HOLLY ENERGY PARTNERS LP - FORM 10-Q

Attached files

file	filename
EX-10.1 - EXHIBIT 10.1 - HOLLY ENERGY PARTNERS LP	exhibit101subordinatemortg.htm
EX-31.2 - EXHIBIT 31.2 - HOLLY ENERGY PARTNERS LP	hepex3126-30x201510q.htm
EX-32.1 - EXHIBIT 32.1 - HOLLY ENERGY PARTNERS LP	hepex3216-30x201510q.htm
EX-31.1 - EXHIBIT 31.1 - HOLLY ENERGY PARTNERS LP	hepex3116-30x201510q.htm
EX-32.2 - EXHIBIT 32.2 - HOLLY ENERGY PARTNERS LP	hepex3226-30x201510q.htm

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, 2015



¨	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	¨

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 June 30, 2015 was 58,657,048.

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 Statements of Partners’ Equity	8

		Notes to Consolidated Financial Statements	9

	Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	26

	Item 3.	Quantitative and Qualitative Disclosures About Market Risk	37

	Item 4.	Controls and Procedures	37

PART II. OTHER INFORMATION			38

	Item 1.	Legal Proceedings	38

	Item 1A.	Risk Factors	38

	Item 6.	Exhibits	38

		SIGNATURES	39

		Index to Exhibits	40

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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, 2014, in “Risk Factors” and in this 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.

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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, 2015			December 31, 2014
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	10,424		$	2,830
Accounts receivable:
Trade	11,286			6,737
Affiliates	28,758			33,392
	40,044			40,129
Prepaid and other current assets	4,738			4,383
Total current assets	55,206			47,342

Properties and equipment, net	1,000,808			980,479
Transportation agreements, net	77,279			80,703
Goodwill	256,498			256,498
Investment in SLC Pipeline	24,280			24,478
Other assets	11,172			12,055
Total assets	$	1,425,243		$	1,401,555

LIABILITIES AND PARTNERS’ EQUITY
Current liabilities:
Accounts payable:
Trade	$	8,317		$	12,642
Affiliates	7,811			5,239
	16,128			17,881

Accrued interest	6,783			6,615
Deferred revenue	9,940			12,432
Accrued property taxes	4,335			2,703
Other current liabilities	4,826			4,571
Total current liabilities	42,012			44,202

Long-term debt	900,905			867,579
Other long-term liabilities	21,132			18,145
Deferred revenue	35,484			29,392

Class B unit	30,305			26,793

Equity:
Partners’ equity:
Common unitholders (58,657,048 units issued and outstanding at June 30, 2015 and December 31, 2014)	441,224			468,813
General partner interest (2% interest)	(139,711		)	(148,405		)
Accumulated other comprehensive loss	(573		)	(46		)
Total partners’ equity	300,940			320,362
Noncontrolling interest	94,465			95,082
Total equity	395,405			415,444
Total liabilities and equity	$	1,425,243		$	1,401,555

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,
	2015			2014			2015			2014
Revenues:
Affiliates	$	68,297		$	64,480		$	140,552		$	136,312
Third parties	15,182			10,518			32,683			25,690
	83,479			74,998			173,235			162,002
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	25,289			24,567			53,255			47,379
Depreciation and amortization	15,063			15,882			29,757			31,470
General and administrative	2,696			2,516			5,986			5,667
	43,048			42,965			88,998			84,516
Operating income	40,431			32,033			84,237			77,486

Other income (expense):
Equity in earnings of SLC Pipeline	631			748			1,365			1,270
Interest expense	(9,056		)	(8,329		)	(17,824		)	(18,783		)
Interest income	3			—			3			3
Loss on early extinguishment of debt	—			—			—			(7,677		)
Other income	71			26			230			34
	(8,351		)	(7,555		)	(16,226		)	(25,153		)
Income before income taxes	32,080			24,478			68,011			52,333
State income tax benefit (expense)	64			(28		)	(37		)	(103		)
Net income	32,144			24,450			67,974			52,230
Allocation of net income attributable to noncontrolling interests	(1,743		)	(1,416		)	(5,770		)	(5,053		)
Net income attributable to Holly Energy Partners	30,401			23,034			62,204			47,177
General partner interest in net income, including incentive distributions	(10,196		)	(8,393		)	(20,006		)	(16,394		)
Limited partners’ interest in net income	$	20,205		$	14,641		$	42,198		$	30,783
Limited partners’ per unit interest in earnings—basic and diluted	$	0.34		$	0.25		$	0.71		$	0.52
Weighted average limited partners’ units outstanding	58,657			58,657			58,657			58,657

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,
	2015			2014			2015			2014
Net income	$	32,144		$	24,450		$	67,974		$	52,230
Other comprehensive income:
Change in fair value of cash flow hedging instruments	(306		)	(1,299		)	(1,586		)	(1,742		)
Reclassification adjustment to net income on partial settlement of cash flow hedge	528			553			1,059			1,091
Other comprehensive income (loss)	222			(746		)	(527		)	(651		)
Comprehensive income before noncontrolling interest	32,366			23,704			67,447			51,579
Allocation of comprehensive income to noncontrolling interests	(1,743		)	(1,416		)	(5,770		)	(5,053		)
Comprehensive income attributable to Holly Energy Partners	$	30,623		$	22,288		$	61,677		$	46,526

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,
	2015			2014
Cash flows from operating activities
Net income	$	67,974		$	52,230
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	29,757			31,470
Gain on sale of assets	(209		)	—
Amortization of deferred charges	930			947
Amortization of restricted and performance units	1,762			1,658
Loss on early extinguishment of debt	—			7,677
(Increase) decrease in operating assets:
Accounts receivable—trade	(4,514		)	(1,446		)
Accounts receivable—affiliates	5,064			1,823
Prepaid and other current assets	(311		)	128
Increase (decrease) in operating liabilities:
Accounts payable—trade	(1,610		)	1,280
Accounts payable—affiliates	2,573			(4,495		)
Accrued interest	168			(3,552		)
Deferred revenue	3,600			2,315
Accrued property taxes	1,632			1,912
Other current liabilities	(242		)	1,153
Other, net	3,890			(737		)
Net cash provided by operating activities	110,464			92,363

Cash flows from investing activities
Additions to properties and equipment	(22,943		)	(38,574		)
Purchase of El Dorado crude tanks	(27,500		)	—
Proceeds from sale of assets	965			—
Distributions in excess of equity in earnings of SLC Pipeline	198			105
Net cash used for investing activities	(49,280		)	(38,469		)

Cash flows from financing activities
Borrowings under credit agreement	254,100			477,100
Repayments of credit agreement borrowings	(221,100		)	(297,100		)
Redemption of senior notes	—			(156,188		)
Distributions to HEP unitholders	(82,614		)	(75,577		)
Distributions to noncontrolling interest	(2,875		)	(2,000		)
Purchase of units for incentive grants	(247		)	(406		)
Other	(854		)	(9		)
Net cash used by financing activities	(53,590		)	(54,180		)

Cash and cash equivalents
Increase (decrease) for the period	7,594			(286		)
Beginning of period	2,830			6,352
End of period	$	10,424		$	6,066

See accompanying notes.

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Table of Contentsril 19,

HOLLY ENERGY PARTNERS, L.P.

CONSOLIDATED STATEMENTS OF PARTNERS' EQUITY

(Unaudited)

(In thousands)



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

Balance December 31, 2014	$	468,813		$	(148,405	)	$	(46	)	$	95,082		$	415,444
Distributions to HEP unitholders	(62,612		)	(20,002		)	—			—			(82,614		)
Distributions to noncontrolling interest	—			—			—			(2,875		)	(2,875		)
Purchase of units for incentive grants	(247		)	—			—			—			(247		)
Amortization of restricted and performance units	1,762			—			—			—			1,762
Class B unit accretion	(3,442		)	(70		)	—			—			(3,512		)
Net income	36,950			28,766			—			2,258			67,974
Other comprehensive loss	—			—			(527		)	—			(527		)
Balance June 30, 2015	$	441,224		$	(139,711	)	$	(573	)	$	94,465		$	395,405

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 39% owned (including the 2% general partner interest) by HollyFrontier Corporation (“HFC”) and its subsidiaries. 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 operate in one reportable segment which represents the aggregation of our petroleum product and crude pipelines business and terminals, tankage and loading rack facilities operation.

We own and operate petroleum product and crude oil pipelines and terminal, tankage and loading rack facilities that support HFC’s refining and marketing operations in the Mid-Continent, Southwest and Rocky Mountain 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”), which owns a 427-mile, 12-inch refined products pipeline running from Woods Cross, Utah to Las Vegas, Nevada (the “UNEV Pipeline”), product terminals near Cedar City, Utah and Las Vegas, Nevada and related assets, and a 25% interest in SLC Pipeline LLC, which owns a 95-mile intrastate crude oil pipeline system (the “SLC Pipeline”) that serves refineries in the Salt Lake City, Utah area.

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, and providing other services at our storage tanks and terminals. We do not take ownership of products that we transport, terminal or store, 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 Form 10-K for the year ended December 31, 2014. 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, 2015.

New Accounting Pronouncements

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. We are evaluating the impact of this standard.

Debt Issuance Costs

In April 2015, an accounting standard update was issued requiring debt issuance costs to be presented as a direct deduction from the carrying amount of the debt liability. The amount of deferred debt issuance costs reported in Long-term assets was $4.7 million and $4.4 million as of June 30, 2015 and December 31, 2014, respectively. This standard will become effective beginning with our 2016 reporting year.


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 and 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:

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HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued


•	(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.

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



		June 30, 2015				December 31, 2014
Financial Instrument	Fair Value Input Level	Carrying Value		Fair Value		Carrying Value		Fair Value
		(In thousands)
Assets:
Interest rate swaps	Level 2	$	134	$	134	$	1,019	$	1,019

Liabilities:
6.5% Senior notes	Level 2	$	296,905	$	295,875	$	296,579	$	291,000
Interest rate swaps	Level 2	707		707		1,065		1,065
		$	297,612	$	296,582	$	297,644	$	292,065

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, 2015		December 31, 2014
	(In thousands)
Pipelines, terminals and tankage	$	1,180,313	$	1,137,157
Land and right of way	65,025		64,458
Construction in progress	57,258		56,228
Other	22,646		22,636
	1,325,242		1,280,479
Less accumulated depreciation	324,434		300,000
	$	1,000,808	$	980,479

On March 6, 2015, we completed the acquisition of an existing crude tank farm adjacent to HFC's El Dorado Refinery from an unrelated third-party for $27.5 million in cash. We recorded the assets acquired and liabilities assumed at their fair values at the date of acquisition based on preliminary valuations. Substantially all of the purchase price was allocated to properties and equipment and no goodwill has been recorded. We expect to finalize the purchase price allocation during the third quarter of 2015. HFC is the main customer of this crude tank farm.

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HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

We capitalized $0.6 million and $0.9 million in interest attributable to construction projects during the six months ended June 30, 2015 and 2014, respectively.

Depreciation expense was $26.0 million and $27.8 million for the six months ended June 30, 2015 and 2014, respectively.


Note 4:	Transportation Agreements

Our transportation agreements represent a portion of the total purchase price of certain assets acquired from Alon in 2005 and from HFC in 2008. 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).

The carrying amounts of our transportation agreements are as follows:



	June 30, 2015		December 31, 2014
	(In thousands)
Alon transportation agreement	$	59,933	$	59,933
HFC transportation agreement	74,231		74,231
Other	50		—
	134,214		134,164
Less accumulated amortization	56,935		53,461
	$	77,279	$	80,703

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 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 5:	Employees, Retirement and Incentive Plans

Direct support for our operations is provided by Holly Logistic Services, L.L.C., 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 $1.7 million and $1.9 million for the three months ended June 30, 2015 and 2014, respectively, and $3.1 million and $3.6 million for the six months ended June 30, 2015 and 2014, respectively.

We have an incentive plan (“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.

As of June 30, 2015, we have three types of incentive-based awards outstanding, which are described below. The compensation cost charged against income was $0.9 million and $0.8 million for the three months ended June 30, 2015 and 2014, respectively, and $1.6 million for each of the the six months ended June 30, 2015 and 2014. 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, 2015, 2,500,000 units were authorized to be granted under our Long-Term Incentive Plan, of which 1,537,167 have not yet been granted, assuming no forfeitures of the unvested units and full achievement of goals for the performance units already granted.

Restricted and Phantom 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.

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HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

In addition, we grant phantom units to certain employees, which vest over a period of one year. Vested units are paid in common units. Full ownership of the units does not transfer to the recipient until the units vest, and the recipients do not have voting or distribution rights on these units until they vest.

The fair value of each restricted unit and phantom unit award is measured at the market price as of the date of grant and is amortized over the vesting period.

A summary of restricted and phantom unit activity and changes during the six months ended June 30, 2015, is presented below:



Restricted and Phantom Units	Units		Weighted Average Grant-Date Fair Value
Outstanding at January 1, 2015 (nonvested)	126,077		$	33.43
Forfeited	(2,849	)	33.57
Outstanding at June 30, 2015 (nonvested)	123,228		$	33.42

As of June 30, 2015, there was $1.7 million of total unrecognized compensation expense related to nonvested restricted unit and phantom unit grants, which is expected to be recognized over a weighted-average period of 1.2 years.

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 based upon the growth in our distributable cash flow per common unit over the performance period, and vest over a period of three years. As of June 30, 2015, estimated unit payouts for outstanding nonvested performance unit awards ranged between 100% and 140%.

No performance units were granted during the six months ended June 30, 2015. Performance units granted in 2014 vest over a three-year performance period ending December 31, 2017. These performance units granted 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, 2015, is presented below:



Performance Units	Units
Outstanding at January 1, 2015 (nonvested)	71,245
Vesting and transfer of common units to recipients	(11,436	)
Outstanding at June 30, 2015 (nonvested)	59,809

The grant-date fair value of performance units vested and transferred to recipients during the six months ended June 30, 2015, was $0.3 million. Based on the weighted average fair value of performance units outstanding at June 30, 2015, of $2.2 million, there was $0.8 million of total unrecognized compensation expense related to nonvested performance units, which is expected to be recognized over a weighted-average period of 1.2 years.


Note 6:	Debt

Credit Agreement

In April 2015, we amended our senior secured revolving credit facility (the “Credit Agreement”) increasing the size of the Credit Agreement from $650 million to $850 million. The Credit Agreement is available to fund capital expenditures, investments, acquisitions, distribution payments and working capital and for general partnership purposes. It is also available to fund letters of credit up to a $50 million sub-limit.

- 12 -

HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

Our obligations under the Credit Agreement are collateralized by substantially all of our assets. Indebtedness under the Credit Agreement is recourse to HEP Logistics Holdings, L.P. (“HEP Logistics”), our general partner, and is guaranteed by our material, wholly-owned subsidiaries. Any recourse to HEP Logistics would be limited to the extent of its assets, which other than its investment in us, are not significant. We may prepay all loans at any time without penalty, except for payment of certain breakage and related costs.

The Credit Agreement imposes certain requirements on us with which we are currently in compliance, including: a prohibition against distribution to unitholders if, before or after the distribution, a potential default or an event of default as defined in the agreement would occur; limitations on our ability to incur debt, make loans, acquire other companies, change the nature of our business, enter into a merger or consolidation, or sell assets; and covenants that require maintenance of a specified EBITDA to interest expense ratio, total debt to EBITDA ratio and senior debt to EBITDA ratio. If an event of default exists under the Credit Agreement, the lenders will be able to accelerate the maturity of the debt and exercise other rights and remedies.

Senior Notes

We have $300 million in aggregate principal amount outstanding of 6.5% senior notes (the "6.5% Senior Notes") maturing March 2020. The 6.5% Senior Notes are unsecured and impose certain restrictive covenants, with which we are currently in compliance, 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. At any time when the 6.5% 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 6.5% Senior Notes.

In March 2014, we redeemed the $150 million aggregate principal amount of 8.25% Senior Notes maturing March 2018 at a redemption cost of $156.2 million, at which time we recognized a $7.7 million early extinguishment loss consisting of a $6.2 million debt redemption premium and unamortized discount and financing costs of $1.5 million. We funded the redemption with borrowings under our Credit Agreement.

Indebtedness under the 6.5% Senior Notes involves recourse to HEP Logistics, our general partner, and is guaranteed by our material, wholly-owned subsidiaries. However, any recourse to HEP Logistics would be limited to the extent of its assets, which, other than its investment in us, are not significant.

Long-term Debt

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



	June 30, 2015			December 31, 2014
	(In thousands)
Credit Agreement	$	604,000		$	571,000
6.5% Senior Notes
Principal	300,000			300,000
Unamortized discount	(3,095		)	(3,421		)
	296,905			296,579

Total long-term debt	$	900,905		$	867,579

Interest Rate Risk Management

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

As of June 30, 2015, we have three interest rate swaps that hedge our exposure to the cash flow risk caused by the effects of LIBOR changes on $305 million of Credit Agreement advances. Our first interest rate swap effectively converts $155 million of our LIBOR based debt to fixed rate debt having an interest rate of 0.99% plus an applicable margin of 2.00% as of June 30, 2015, which equaled an effective interest rate of 2.99%. This swap contract matures in February 2016. We have two additional interest rate swaps with identical terms which effectively convert $150 million of our LIBOR based debt to fixed rate debt having an interest rate of 0.74% plus an applicable margin of 2.00% as of June 30, 2015, which equaled an effective interest rate of 2.74%. Both of these swap contracts mature in July 2017.

- 13 -

HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

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 that these interest rate swaps are effective in offsetting the variability in interest payments on $305 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 future interest payments on $305 million of our variable rate debt. Any ineffectiveness is recorded directly to interest expense. As of June 30, 2015, we had no ineffectiveness on our cash flow hedges.

At June 30, 2015, we have accumulated other comprehensive loss of $0.6 million that relates to our current cash flow hedging instruments. Approximately $0.6 million will be transferred from accumulated other comprehensive loss into interest expense as interest is paid on the underlying swap agreement over the next twelve-month period, assuming interest rates remain unchanged.

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, 2015
Interest rate swaps designated as cash flow hedging instrument:
Variable-to-fixed interest rate swap contract ($155 million of LIBOR-based debt interest)	Other current liabilities	$	(707	)	Accumulated other comprehensive loss	$	(707	)
Variable-to-fixed interest rate swap contracts ($150 million of LIBOR-based debt interest)	Other long-term assets	134			Accumulated other comprehensive income	134
		$	(573	)		$	(573	)

December 31, 2014
Interest rate swaps designated as cash flow hedging instrument:
Variable-to-fixed interest rate swap contract ($155 million of LIBOR-based debt interest)	Other long-term liabilities	$	(1,065	)	Accumulated other comprehensive loss	$	(1,065	)
Variable-to-fixed interest rate swap contracts ($150 million of LIBOR-based debt interest)	Other long-term assets	1,019			Accumulated other comprehensive income	1,019
		$	(46	)		$	(46	)

Interest Expense and Other Debt Information

Interest expense consists of the following components:



	Six Months Ended June 30,
	2015		2014
	(In thousands)
Interest on outstanding debt:
Credit Agreement, net of interest on interest rate swaps	$	7,488	$	6,165
6.5% Senior Notes	9,757		9,696
8.25% Senior Notes	—		2,544
Amortization of discount and deferred debt issuance costs	930		948
Commitment fees	261		293
Total interest incurred	18,436		19,646
Less capitalized interest	612		863
Net interest expense	$	17,824	$	18,783
Cash paid for interest	$	17,280	$	22,249

- 14 -

HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued


Note 7:	Significant Customers

All revenues are domestic revenues, of which 92% are currently generated from our two largest customers: HFC and Alon. The vast majority of our revenues are derived from activities conducted in the southwest United States.

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



	Three Months Ended June 30,				Six Months Ended June 30,
	2015		2014		2015		2014
HFC	82	%	86	%	81	%	84	%
Alon	10	%	7	%	10	%	9	%


Note 8:	Related Party Transactions

We serve HFC's refineries under long-term pipeline and terminal, tankage and throughput agreements expiring from 2019 to 2026. Under these agreements, HFC agrees to transport, store and throughput volumes of refined product and crude oil on our pipelines and terminal, tankage and loading rack facilities that result in minimum annual payments to us. These minimum annual payments or revenues are subject to annual tariff 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, 2015, these agreements with HFC will result in minimum annual payments to us of $236.6 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 $2.4 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 $68.3 million and $64.5 million for the three months ended June 30, 2015 and 2014, respectively, and $140.6 million and $136.3 million for the six months ended June 30, 2015 and 2014, 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, 2015 and 2014, and $1.2 million for each of the six months ended June 30, 2015 and 2014.


•	We reimbursed HFC for costs of employees supporting our operations of $7.5 million and $9.6 million for the three months ended June 30, 2015 and 2014, respectively, and $16.2 million and $18.8 million for the six months ended June 30, 2015 and 2014, respectively.


•	HFC reimbursed us $4.4 million and $3.9 million for the three months ended June 30, 2015 and 2014, respectively, for certain reimbursable costs and capital projects and $7.0 million and $8.4 million for the six months ended June 30, 2015 and 2014, respectively.


•	We distributed $22.3 million and $19.8 million for the three months ended June 30, 2015 and 2014, respectively, to HFC as regular distributions on its common units and general partner interest, including general partner incentive distributions. For the six months ended June 30, 2015 and 2014, we distributed $43.9 million and $39.0 million, respectively


•	Accounts receivable from HFC were $28.8 million and $33.4 million at June 30, 2015, and December 31, 2014, respectively.


•	Accounts payable to HFC were $7.8 million and $5.2 million at June 30, 2015, and December 31, 2014, respectively.


•	Revenues for the six months ended June 30, 2015 and 2014, include $6.0 million and $7.6 million, respectively, of shortfall payments billed in 2014 and 2013, as HFC did not exceed its minimum volume commitment in any of the subsequent

- 15 -

HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

four quarters. Deferred revenue in the consolidated balance sheets at June 30, 2015, and December 31, 2014, includes $5.4 million and $7.3 million, respectively, relating to certain shortfall billings. It is possible that HFC may not exceed its minimum obligations to receive credit for any of the $5.4 million deferred at June 30, 2015.


Note 9:	Partners’ Equity

As of June 30, 2015, HFC held 22,380,030 of our common units and the 2% general partner interest, which together constituted a 39% ownership interest in us.

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 the amount of incentive distributions is 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,
	2015		2014		2015		2014
	(In thousands)
General partner interest in net income	$	412	$	299	$	861	$	628
General partner incentive distribution	9,784		8,094		19,145		15,766
Total general partner interest in net income	$	10,196	$	8,393	$	20,006	$	16,394

In addition to the allocation of net income as presented above, the consolidated statement of partners equity for the six months ended June 30, 2015, reflects a cumulative revision of net income allocations between the general partnership interest and common units of approximately $8.8 million for net income related to years ended 2014 and prior. This revision had no impact on historical limited partners’ per unit interest in earnings.

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 23, 2015, we announced our cash distribution for the second quarter of 2015 of $0.5450 per unit. The distribution is payable on all common and general partner units and will be paid August 14, 2015, to all unitholders of record on August 3, 2015.

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,
	2015		2014		2015		2014
	(In thousands, except per unit data)
General partner interest in distribution	$	877	$	807	$	1,738	$	1,597
General partner incentive distribution	9,784		8,094		19,145		15,766
Total general partner distribution	10,661		8,901		20,883		17,363
Limited partner distribution	31,968		30,209		63,496		59,977
Total regular quarterly cash distribution	$	42,629	$	39,110	$	84,379	$	77,340
Cash distribution per unit applicable to limited partners	$	0.5450	$	0.5150	$	1.0825	$	1.0225

- 16 -

HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

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:	Environmental

We incurred no environmental expense for the three months ended June 30, 2015, and $0.9 million for environmental remediation obligations for the three months ended June 30, 2014. For the six months ended June 30, 2015 and 2014, we incurred environmental expenses of $4.2 million and $0.7 million, respectively. During the six months ended June 30, 2015, we increased certain environmental cost accruals to reflect revisions to the cost estimates and the time frame for which the related environmental remediation and monitoring activities are expected to occur. The accrued environmental liability reflected in our consolidated balance sheets was $15.3 million and $12.0 million at June 30, 2015 and December 31, 2014, respectively, of which $12.3 million and $8.7 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, 2015, and December 31, 2014, our accrued environmental liability included $6.6 million and $6.8 million, respectively, for HFC indemnified liabilities. In addition, as of June 30, 2015, and December 31, 2014, $6.6 million and $6.8 million, respectively, was included in other assets representing amounts due from HFC related to indemnifications for environmental remediation liabilities.


Note 11:	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 operation or cash flows.


Note 12:	Supplemental Guarantor/Non-Guarantor Financial Information

Obligations of HEP (“Parent”) under the 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.

- 17 -

HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

Condensed Consolidating Balance Sheet



June 30, 2015	Parent		Guarantor Restricted Subsidiaries		Non-Guarantor Non-Restricted Subsidiaries		Eliminations			Consolidated
	(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	—	$	7,350	$	3,074	$	—		$	10,424
Accounts receivable	2		35,771		4,442		(171		)	40,044
Prepaid and other current assets	82		3,395		1,261		—			4,738
Total current assets	84		46,516		8,777		(171		)	55,206

Properties and equipment, net	—		624,509		376,299		—			1,000,808
Investment in subsidiaries	603,118		283,393		—		(886,511		)	—
Transportation agreements, net	—		77,279		—		—			77,279
Goodwill	—		256,498		—		—			256,498
Investment in SLC Pipeline	—		24,280		—		—			24,280
Other assets	1,344		9,828		—		—			11,172
Total assets	$	604,546	$	1,322,303	$	385,076	$	(886,682	)	$	1,425,243

LIABILITIES AND PARTNERS’ EQUITY
Current liabilities:
Accounts payable	$	—	$	15,343	$	956	$	(171	)	$	16,128
Accrued interest	6,500		283		—		—			6,783
Deferred revenue	—		6,440		3,500		—			9,940
Accrued property taxes	—		1,739		2,596		—			4,335
Other current liabilities	24		4,801		1		—			4,826
Total current liabilities	6,524		28,606		7,053		(171		)	42,012

Long-term debt	296,905		604,000		—		—			900,905
Other long-term liabilities	177		20,790		165		—			21,132
Deferred revenue	—		35,484		—		—			35,484
Class B unit	—		30,305		—		—			30,305
Equity - partners	300,940		603,118		377,858		(980,976		)	300,940
Equity - noncontrolling interest	—		—		—		94,465			94,465
Total liabilities and partners’ equity	$	604,546	$	1,322,303	$	385,076	$	(886,682	)	$	1,425,243

- 18 -

HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

Condensed Consolidating Balance Sheet



December 31, 2014	Parent		Guarantor Restricted Subsidiaries		Non-Guarantor Non-Restricted Subsidiaries		Eliminations			Consolidated
	(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	2	$	2,828	$	—	$	—		$	2,830
Accounts receivable	—		34,274		6,044		(189		)	40,129
Prepaid and other current assets	212		2,856		1,315		—			4,383
Total current assets	214		39,958		7,359		(189		)	47,342

Properties and equipment, net	—		596,988		383,491		—			980,479
Investment in subsidiaries	622,100		285,247		—		(907,347		)	—
Transportation agreements, net	—		80,703		—		—			80,703
Goodwill	—		256,498		—		—			256,498
Investment in SLC Pipeline	—		24,478		—		—			24,478
Other assets	1,319		10,736		—		—			12,055
Total assets	$	623,633	$	1,294,608	$	390,850	$	(907,536	)	$	1,401,555

LIABILITIES AND PARTNERS’ EQUITY
Current liabilities:
Accounts payable	$	—	$	15,495	$	2,575	$	(189	)	$	17,881
Accrued interest	6,500		115		—		—			6,615
Deferred revenue	—		5,672		6,760		—			12,432
Accrued property taxes	—		1,902		801		—			2,703
Other current liabilities	45		4,408		118		—			4,571
Total current liabilities	6,545		27,592		10,254		(189		)	44,202

Long-term debt	296,579		571,000		—		—			867,579
Other long-term liabilities	147		17,731		267		—			18,145
Deferred revenue	—		29,392		—		—			29,392
Class B unit	—		26,793		—		—			26,793
Equity - partners	320,362		622,100		380,329		(1,002,429		)	320,362
Equity - noncontrolling interest	—		—		—		95,082			95,082
Total liabilities and partners’ equity	$	623,633	$	1,294,608	$	390,850	$	(907,536	)	$	1,401,555

- 19 -

HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

Condensed Consolidating Statement of Comprehensive Income



Three Months Ended June 30, 2015	Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-restricted Subsidiaries			Eliminations			Consolidated
	(In thousands)
Revenues:
Affiliates	$	—		$	64,727		$	3,545		$	25		$	68,297
Third parties	—			11,895			3,287			—			15,182
	—			76,622			6,832			25			83,479
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	—			22,111			3,153			25			25,289
Depreciation and amortization				11,316			3,747			—			15,063
General and administrative	637			2,059			—			—			2,696
	637			35,486			6,900			25			43,048
Operating income (loss)	(637		)	41,136			(68		)	—			40,431
Equity in earnings (loss) of subsidiaries	36,111			(88		)	—			(36,023		)	—
Equity in earnings of SLC Pipeline	—			631			—			—			631
Interest expense	(5,073		)	(3,983		)	—			—			(9,056		)
Interest income	—			3			—			—			3
Other income (expense)	—			120			(49		)	—			71
	31,038			(3,317		)	(49		)	(36,023		)	(8,351		)
Income (loss) before income taxes	30,401			37,819			(117		)	(36,023		)	32,080
State income tax benefit	—			64			—			—			64
Net income (loss)	30,401			37,883			(117		)	(36,023		)	32,144
Allocation of net income attributable to noncontrolling interests	—			—			—			(1,743		)	(1,743		)
Net income (loss) attributable to Holly Energy Partners	30,401			37,883			(117		)	(37,766		)	30,401
Other comprehensive income (loss)	222			222			—			(222		)	222
Comprehensive income (loss)	$	30,623		$	38,105		$	(117	)	$	(37,988	)	$	30,623

- 20 -

HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

Condensed Consolidating Statement of Comprehensive Income



Three Months Ended June 30, 2014	Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-Restricted Subsidiaries			Eliminations			Consolidated
	(In thousands)
Revenues:
Affiliates	$	—		$	61,427		$	3,359		$	(306	)	$	64,480
Third parties	—			8,533			1,985			—			10,518
	—			69,960			5,344			(306		)	74,998
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	—			22,179			2,694			(306		)	24,567
Depreciation and amortization	—			12,288			3,594			—			15,882
General and administrative	585			1,931			—			—			2,516
	585			36,398			6,288			(306		)	42,965
Operating income (loss)	(585		)	33,562			(944		)	—			32,033
Equity in earnings (loss) of subsidiaries	28,631			(708		)	—			(27,923		)	—
Equity in earnings of SLC Pipeline	—			748			—			—			748
Interest expense	(5,012		)	(3,317		)	—			—			(8,329		)
Other income	—			26			—			—			26
	23,619			(3,251		)	—			(27,923		)	(7,555		)
Income (loss) before income taxes	23,034			30,311			(944		)	(27,923		)	24,478
State income tax expense	—			(28		)	—			—			(28		)
Net income (loss)	23,034			30,283			(944		)	(27,923		)	24,450
Allocation of net income attributable to noncontrolling interests	—			—			—			(1,416		)	(1,416		)
Net income (loss) attributable to Holly Energy Partners	23,034			30,283			(944		)	(29,339		)	23,034
Other comprehensive income (loss)	(746		)	(746		)	—			746			(746		)
Comprehensive income (loss)	$	22,288		$	29,537		$	(944	)	$	(28,593	)	$	22,288

- 21 -

HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

Condensed Consolidating Statement of Comprehensive Income



Six Months Ended June 30, 2015	Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-restricted Subsidiaries			Eliminations			Consolidated
	(In thousands)
Revenues:
Affiliates	$	—		$	127,783		$	12,769		$	—		$	140,552
Third parties	—			23,282			9,401			—			32,683
	—			151,065			22,170			—			173,235
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	—			47,642			5,613			—			53,255
Depreciation and amortization	—			22,278			7,479			—			29,757
General and administrative	1,700			4,286			—			—			5,986
	1,700			74,206			13,092			—			88,998
Operating income (loss)	(1,700		)	76,859			9,078			—			84,237
Equity in earnings (loss) of subsidiaries	74,044			6,772			—			(80,816		)	—
Equity in earnings of SLC Pipeline	—			1,365			—			—			1,365
Interest expense	(10,140		)	(7,684		)	—			—			(17,824		)
Interest income	—			3			—			—			3
Other income (expense)	—			279			(49		)	—			230
	63,904			735			(49		)	(80,816		)	(16,226		)
Income (loss) before income taxes	62,204			77,594			9,029			(80,816		)	68,011
State income tax expense	—			(37		)	—			—			(37		)
Net income (loss)	62,204			77,557			9,029			(80,816		)	67,974
Allocation of net income attributable to noncontrolling interests	—			—			—			(5,770		)	(5,770		)
Net income (loss) attributable to Holly Energy Partners	62,204			77,557			9,029			(86,586		)	62,204
Other comprehensive income (loss)	(527		)	(527		)	—			527			(527		)
Comprehensive income (loss)	$	61,677		$	77,030		$	9,029		$	(86,059	)	$	61,677

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HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

Condensed Consolidating Statement of Comprehensive Income



Six Months Ended June 30, 2014	Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-Restricted Subsidiaries		Eliminations			Consolidated
	(In thousands)
Revenues:
Affiliates	$	—		$	123,042		$	13,883	$	(613	)	$	136,312
Third parties	—			19,614			6,076		—			25,690
	—			142,656			19,959		(613		)	162,002
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	—			42,330			5,662		(613		)	47,379
Depreciation and amortization	—			24,281			7,189		—			31,470
General and administrative	1,643			4,024			—		—			5,667
	1,643			70,635			12,851		(613		)	84,516
Operating income (loss)	(1,643		)	72,021			7,108		—			77,486
Equity in earnings (loss) of subsidiaries	69,195			5,331			—		(74,526		)	—
Equity in earnings of SLC Pipeline	—			1,270			—		—			1,270
Interest expense	(12,698		)	(6,085		)	—		—			(18,783		)
Interest income	—			3			—		—			3
Loss on early extinguishment of debt	(7,677		)	—			—		—			(7,677		)
Other income	—			34			—		—			34
	48,820			553			—		(74,526		)	(25,153		)
Income (loss) before income taxes	47,177			72,574			7,108		(74,526		)	52,333
State income tax expense	—			(103		)	—		—			(103		)
Net income (loss)	47,177			72,471			7,108		(74,526		)	52,230
Allocation of net income attributable to noncontrolling interests	—			—			—		(5,053		)	(5,053		)
Net income (loss) attributable to Holly Energy Partners	47,177			72,471			7,108		(79,579		)	47,177
Other comprehensive income (loss)	(651		)	(651		)	—		651			(651		)
Comprehensive income (loss)	$	46,526		$	71,820		$	7,108	$	(78,928	)	$	46,526

- 23 -

HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

Condensed Consolidating Statement of Cash Flows



Six Months Ended June 30, 2015	Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-Restricted Subsidiaries			Eliminations			Consolidated
	(In thousands)
Cash flows from operating activities	$	(9,639	)	$	111,517		$	15,358		$	(6,772	)	$	110,464

Cash flows from investing activities
Additions to properties and equipment	—			(22,159		)	(784		)	—			(22,943		)
Purchase of El Dorado crude tanks	—			(27,500		)	—			—			(27,500		)
Proceeds from sale of assets	—			965			—			—			965
Distributions from UNEV	—			1,853			—			(1,853		)	—
Distributions in excess of equity in earnings in SLC Pipeline	—			198			—			—			198
	—			(46,643		)	(784		)	(1,853		)	(49,280		)

Cash flows from financing activities
Net borrowings under credit agreement	—			33,000			—			—			33,000
Net intercompany financing activities	92,498			(92,498		)	—			—			—
Distributions to HEP unitholders	(82,614		)	—			—			—			(82,614		)
Distributions to noncontrolling interests	—			—			(11,500		)	8,625			(2,875		)
Purchase of units for incentive grants	(247		)	—			—			—			(247		)
Other	—			(854		)	—			—			(854		)
	9,637			(60,352		)	(11,500		)	8,625			(53,590		)

Cash and cash equivalents
Increase (decrease) for the period	(2		)	4,522			3,074			—			7,594
Beginning of period	2			2,828			—			—			2,830
End of period	$	—		$	7,350		$	3,074		$	—		$	10,424

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HOLLY ENERGY PARTNERS, L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited) Continued

Condensed Consolidating Statement of Cash Flows



Six Months Ended June 30, 2014	Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-Restricted Subsidiaries			Eliminations			Consolidated
	(In thousands)
Cash flows from operating activities	$	(15,764	)	$	96,308		$	11,819		$	—		$	92,363

Cash flows from investing activities
Additions to properties and equipment	—			(33,831		)	(4,743		)	—			(38,574		)
Distributions from noncontrolling interest	—			6,000			—			(6,000		)	—
Distributions in excess of equity in earnings of SLC Pipeline	—			105			—			—			105
	—			(27,726		)	(4,743		)	(6,000		)	(38,469		)

Cash flows from financing activities
Net repayments under credit agreement	—			180,000			—			—			180,000
Net intercompany financing activities	247,935			(247,935		)	—			—			—
Redemption of senior notes	(156,188		)	—			—			—			(156,188		)
Distributions to HEP unitholders	(75,577		)	—			—			—			(75,577		)
Distributions to noncontrolling interests	—			—			(8,000		)	6,000			(2,000		)
Purchase of units for incentive grants	(406		)	—			—			—			(406		)
Other	—			(9		)	—			—			(9		)
	15,764			(67,944		)	(8,000		)	6,000			(54,180		)

Cash and cash equivalents
Increase (decrease) for the period	—			638			(924		)	—			(286		)
Beginning of period	2			1,447			4,903			—			6,352
End of period	$	2		$	2,085		$	3,979		$	—		$	6,066

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Table of Contentsril 19,

HOLLY ENERGY PARTNERS, L.P.


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. We own and operate petroleum product and crude pipelines and terminal, tankage and loading rack facilities that support the refining and marketing operations of HollyFrontier Corporation (“HFC”) in the Mid-Continent, Southwest and Rocky Mountain regions of the United States and Alon USA, Inc’s (“Alon”) refinery in Big Spring, Texas. HFC owns a 39% interest in us, including the 2% general partnership interest. Additionally, we own a 75% interest in UNEV Pipeline, LLC (“UNEV”), the owner of a pipeline running from Woods Cross, Utah to Las Vegas, Nevada (the “UNEV

Pipeline”), product terminals and a 25% interest in SLC Pipeline, LLC, a 95-mile intrastate crude oil pipeline system (the “SLC Pipeline”), that serves refineries in the Salt Lake City, Utah area.

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 and providing other services at our storage tanks and terminals. We do not take ownership of products that we transport, terminal or store, and therefore, we are not directly exposed to changes in commodity prices.

We have a long-term strategic relationship with HFC. Our current growth plan is to continue 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 to work with HFC on logistic asset acquisitions in conjunction with HFC’s refinery acquisition strategies. 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.

Agreements with HFC and Alon

We serve HFC’s refineries under long-term pipeline and terminal, tankage and throughput agreements expiring from 2019 to 2026. Under these agreements, HFC has agreed to transport, store and throughput volumes of refined product and crude oil on our pipelines and terminal, tankage and loading rack facilities that result in minimum annual payments to us. These minimum annual payments or revenues are subject to annual tariff 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, 2015, these agreements with HFC will result in minimum annual payments to us of $236.6 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.

We also have a pipelines and terminals agreement with Alon expiring in 2020 under which Alon 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. We also have a capacity lease agreement under which we lease Alon space on our Orla to El Paso pipeline for the shipment of refined product. The terms under this agreement expire beginning in 2018 through 2022. As of June 30, 2015, these agreements with Alon will result in minimum annual payments to us of $33.3 million.

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

Under certain provisions of an omnibus agreement we have with HFC (“Omnibus Agreement”), we pay HFC an annual administrative fee, currently $2.4 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 separately charged to us by HFC. We also reimburse HFC and its affiliates for direct expenses they incur on our behalf.

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Table of Contentsril 19,

RESULTS OF OPERATIONS (Unaudited)

Income, Distributable Cash Flow and Volumes

The following tables present income, distributable cash flow and volume information for the three and the six months ended June 30, 2015 and 2014.



	Three Months Ended June 30,						Change from
	2015			2014			2014
	(In thousands, except per unit data)
Revenues:
Pipelines:
Affiliates—refined product pipelines	$	18,245		$	17,536		$	709
Affiliates—intermediate pipelines	7,172			6,683			489
Affiliates—crude pipelines	15,096			13,032			2,064
	40,513			37,251			3,262
Third parties—refined product pipelines	11,213			7,480			3,733
	51,726			44,731			6,995
Terminals, tanks and loading racks:
Affiliates	27,784			27,229			555
Third parties	3,969			3,038			931
	31,753			30,267			1,486
Total revenues	83,479			74,998			8,481
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	25,289			24,567			722
Depreciation and amortization	15,063			15,882			(819		)
General and administrative	2,696			2,516			180
	43,048			42,965			83
Operating income	40,431			32,033			8,398
Other income (expense):
Equity in earnings of SLC Pipeline	631			748			(117		)
Interest expense, including amortization	(9,056		)	(8,329		)	(727		)
Interest income	3			—			3
Other	71			26			45
	(8,351		)	(7,555		)	(796		)
Income before income taxes	32,080			24,478			7,602
State income tax benefit (expense)	64			(28		)	92
Net income	32,144			24,450			7,694
Allocation of net income attributable to noncontrolling interests	(1,743		)	(1,416		)	(327		)
Net income attributable to Holly Energy Partners	30,401			23,034			7,367
General partner interest in net income, including incentive distributions ⁽¹⁾	(10,196		)	(8,393		)	(1,803		)
Limited partners’ interest in net income	$	20,205		$	14,641		$	5,564
Limited partners’ earnings per unit—basic and diluted ⁽¹⁾	$	0.34		$	0.25		$	0.09
Weighted average limited partners’ units outstanding	58,657			58,657			—
EBITDA ⁽²⁾	$	54,453		$	47,273		$	7,180
Distributable cash flow ⁽³⁾	$	47,299		$	43,495		$	3,804

Volumes (bpd)
Pipelines:
Affiliates—refined product pipelines	121,982			119,328			2,654
Affiliates—intermediate pipelines	143,140			143,396			(256		)
Affiliates—crude pipelines	295,793			178,564			117,229
	560,915			441,288			119,627
Third parties—refined product pipelines	73,659			43,858			29,801
	634,574			485,146			149,428
Terminals and loading racks:
Affiliates	281,318			269,260			12,058
Third parties	79,133			56,563			22,570
	360,451			325,823			34,628
Total for pipelines and terminal assets (bpd)	995,025			810,969			184,056

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Table of Contentsril 19,



	Six Months Ended June 30,						Change from
	2015			2014			2014
	(In thousands, except per unit data)
Revenues:
Pipelines:
Affiliates—refined product pipelines	$	40,786		$	41,709		$	(923	)
Affiliates—intermediate pipelines	14,034			14,594			(560		)
Affiliates—crude pipelines	32,090			25,650			6,440
	86,910			81,953			4,957
Third parties—refined product pipelines	24,936			19,098			5,838
	111,846			101,051			10,795
Terminals, tanks and loading racks:
Affiliates	53,642			54,359			(717		)
Third parties	7,747			6,592			1,155
	61,389			60,951			438
Total revenues	173,235			162,002			11,233
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	53,255			47,379			5,876
Depreciation and amortization	29,757			31,470			(1,713		)
General and administrative	5,986			5,667			319
	88,998			84,516			4,482
Operating income	84,237			77,486			6,751
Other income (expense):
Equity in earnings of SLC Pipeline	1,365			1,270			95
Interest expense, including amortization	(17,824		)	(18,783		)	959
Interest income	3			3			—
Loss on early extinguishment of debt	—			(7,677		)	7,677
Other	230			34			196
	(16,226		)	(25,153		)	8,927
Income before income taxes	68,011			52,333			15,678
State income tax expense	(37		)	(103		)	66
Net income	67,974			52,230			15,744
Allocation of net income attributable to noncontrolling interests	(5,770		)	(5,053		)	(717		)
Net income attributable to Holly Energy Partners	62,204			47,177			15,027
General partner interest in net income, including incentive distributions ⁽¹⁾	(20,006		)	(16,394		)	(3,612		)
Limited partners’ interest in net income	$	42,198		$	30,783		$	11,415
Limited partners’ earnings per unit—basic and diluted ⁽¹⁾	$	0.71		$	0.52		$	0.19
Weighted average limited partners’ units outstanding	58,657			58,657			—
EBITDA ⁽²⁾	$	109,819		$	105,207		$	4,612
Distributable cash flow ⁽³⁾	$	93,189		$	85,303		$	7,886

Volumes (bpd)
Pipelines:
Affiliates—refined product pipelines	118,724			121,239			(2,515		)
Affiliates—intermediate pipelines	140,620			141,015			(395		)
Affiliates—crude pipelines	289,285			177,763			111,522
	548,629			440,017			108,612
Third parties—refined product pipelines	72,546			55,014			17,532
	621,175			495,031			126,144
Terminals and loading racks:
Affiliates	276,823			265,966			10,857
Third parties	76,574			67,075			9,499
	353,397			333,041			20,356
Total for pipelines and terminal assets (bpd)	974,572			828,072			146,500

(1)

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Table of Contentsril 19,

(2)

Earnings before interest, taxes, depreciation and amortization (“EBITDA”) is calculated as net income attributable to Holly Energy Partners plus (i) interest expense and loss on early extinguishment of debt, net of interest income, (ii) state income tax and (iii) depreciation and amortization. EBITDA is not a calculation based upon generally accepted accounting principles (“GAAP”). However, the amounts included in the EBITDA calculation are derived from amounts included in our consolidated financial statements operations. EBITDA should not be considered as an alternative to net income attributable to Holly Energy Partners or operating income, as an indication of our operating performance or as an alternative to operating cash flow as a measure of liquidity. EBITDA is not necessarily comparable to similarly titled measures of other companies. EBITDA is presented here because it is a widely used financial indicator used by investors and analysts to measure performance. EBITDA is also used by our management for internal analysis and as a basis for compliance with financial covenants. Set forth below is our calculation of EBITDA.



	Three Months Ended June 30,					Six Months Ended June 30,
	2015			2014		2015			2014
	(In thousands)
Net income attributable to Holly Energy Partners	$	30,401		$	23,034	$	62,204		$	47,177
Add (subtract):
Interest expense	8,562			7,893		16,894			17,836
Interest income	(3		)	—		(3		)	(3		)
Amortization of discount and deferred debt issuance costs	494			436		930			947
Loss on early extinguishment of debt	—			—		—			7,677
State income tax (benefit) expense	(64		)	28		37			103
Depreciation and amortization	15,063			15,882		29,757			31,470
EBITDA	$	54,453		$	47,273	$	109,819		$	105,207

(3)

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.



	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
	(In thousands)
Net income attributable to Holly Energy Partners	$	30,401		$	23,034		$	62,204		$	47,177
Add (subtract):
Depreciation and amortization	15,063			15,882			29,757			31,470
Amortization of discount and deferred debt issuance costs	494			436			930			947
Loss on early extinguishment of debt	—			—			—			7,677
Increase (decrease) in deferred revenue related to minimum revenue commitments	1,355			4,760			(2,195		)	(1,138		)
Maintenance capital expenditures⁽⁴⁾	(1,870		)	(842		)	(3,519		)	(1,691		)
Increase (decrease) in environmental liability	(386		)	(3		)	3,471			361
Increase (decrease) in reimbursable deferred revenue	1,537			(629		)	992			(1,211		)
Other non-cash adjustments	705			857			1,549			1,711
Distributable cash flow	$	47,299		$	43,495		$	93,189		$	85,303

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Table of Contentsril 19,


(4)	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.



	June 30, 2015		December 31, 2014
	(In thousands)
Balance Sheet Data
Cash and cash equivalents	$	10,424	$	2,830
Working capital	$	13,194	$	3,140
Total assets	$	1,425,243	$	1,401,555
Long-term debt	$	900,905	$	867,579
Partners’ equity ⁽⁵⁾	$	300,940	$	320,362

(5)

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 partners’ equity since our regular quarterly distributions have exceeded our quarterly net income attributable to HEP. 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 June 30, 2015 Compared with Three Months Ended June 30, 2014

Summary

Net income attributable to Holly Energy Partners for the second quarter was $30.4 million ($0.34 per basic and diluted limited partner unit) compared to $23.0 million ($0.25 per basic and diluted limited partner unit) for the second quarter of 2014. The increase in earnings is primarily due to higher pipeline volumes and annual tariff increases.

Our major shippers are obligated to make deficiency payments to us if they do not meet their minimum volume shipping obligations. Revenues for the three months ended June 30, 2015, include the recognition of $0.5 million of prior shortfalls billed to shippers in 2014 compared to revenues at June 30, 2014, which included the recognition of $0.2 million of prior shortfalls billed to shippers in 2013. Additional shortfall billings of $2.3 million associated with certain guaranteed shipping contracts were deferred during the three months ended June 30, 2015. Such deferred revenue will be recognized in earnings either as (a) payment for shipments in excess of guaranteed levels, if and to the extent the pipeline system will have the necessary capacity for shipments in excess of guaranteed levels, or (b) when shipping rights expire unused over the contractual make-up period.

Revenues

Revenues for the quarter were $83.5 million, an $8.5 million increase compared to the second quarter of 2014 due to the effect of higher pipeline volumes and annual tariff increases. The volume increase resulted in overall pipeline volumes being up 31% compared to the three months ended June 30, 2014 largely due to increased volumes from the New Mexico gathering system expansion as well as lower volumes in the second quarter of 2014 resulting from major maintenance performed at Alon's Big Spring refinery.

Revenues from our refined product pipelines were $29.5 million, an increase of $4.4 million compared to the second quarter of 2014, due to increased volumes and annual tariff increases. Shipments averaged 195.6 mbpd compared to 163.2 mbpd for the second quarter of 2014 largely due to lower volumes in the second quarter of 2014 resulting from major maintenance performed at Alon's Big Spring refinery.

Revenues from our intermediate pipelines were $7.2 million, an increase of $0.5 million, on shipments averaging 143.1 mbpd compared to 143.4 mbpd for the second quarter of 2014. Revenues increased mainly due to a $0.3 million increase in deferred revenue realized.

Revenues from our crude pipelines were $15.1 million, an increase of $2.1 million, on shipments averaging 295.8 mbpd compared to 178.6 mbpd for the second quarter of 2014. Revenues increased mainly due to a $2.1 million increase in revenue from the New Mexico gathering system expansion. The increase in volumes is due to increased crude production in the Artesia Basin as well as the reversal of the Roadrunner pipeline, which made it possible for HFC to purchase and HEP to transport crude volumes in excess of HFC refining capacity.

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Table of Contentsril 19,

Revenues from terminal, tankage and loading rack fees were $31.8 million, an increase of $1.5 million compared to the second quarter of 2014. Refined products terminalled in our facilities averaged 360.5 mbpd compared to 325.8 mbpd for the second quarter of 2014 largely due to lower volumes in the second quarter of 2014 resulting from major maintenance performed at Alon's Big Spring refinery. Revenues increased due to our first quarter 2015 acquisition of an existing crude tank farm adjacent to HFC's El Dorado refinery as well as increased volumes and annual tariff increases.

Operations Expense

Operations expense for the three months ended June 30, 2015, increased by $0.7 million compared to the three months ended June 30, 2014. This increase is mainly due to an increase in maintenance project expense offset by lower employee costs due to secondment of employees in El Dorado and Cheyenne.

Depreciation and Amortization

Depreciation and amortization for the three months ended June 30, 2015, decreased by $0.8 million compared to the three months ended June 30, 2014. The decrease is due principally to lower accelerated tank depreciation and tank write-downs.

General and Administrative

General and administrative costs for the three months ended June 30, 2015, increased by $0.2 million compared to the three months ended June 30, 2014.

Equity in Earnings of SLC Pipeline

Our equity in earnings of the SLC Pipeline was $0.6 million and $0.7 million for the three months ended June 30, 2015 and 2014, respectively.

Interest Expense

Interest expense for the three months ended June 30, 2015, totaled $9.1 million, an increase of $0.7 million compared to the three months ended June 30, 2014. The increase is primarily due to a higher carrying balance on the Credit Agreement. Our aggregate effective interest rates were 4.0% for each of the three months ended June 30, 2015 and 2014, respectively.

State Income Tax

We recorded a state income tax benefit of $64,000 and state income tax expense of $28,000 for the three months ended June 30, 2015 and 2014, respectively. All tax expense is solely attributable to the Texas margin tax.

Results of Operations—Six Months Ended June 30, 2015 Compared with Six Months Ended June 30, 2014

Summary

Net income attributable to Holly Energy Partners for the six months ended June 30, 2015, was $62.2 million compared to $47.2 million for the six months ended June 30, 2014. The increase in net income is due primarily to higher pipeline volumes, annual tariff increases and lower interest expense in addition to a charge of $7.7 million in the first quarter of 2014 related to the redemption of the $150 million aggregate principal amount of our 8.25% Senior Notes maturing March 2018 (the "8.25% Senior Notes").

Revenues for the six months ended June 30, 2015, include the recognition of $8.0 million of prior shortfalls billed to shippers in 2014 as they did not meet their minimum volume commitments within the contractual makeup period. Deficiency payments of $5.0 million associated with certain guaranteed shipping contracts were deferred during the six months ended June 30, 2015. Such deferred revenue will be recognized in earnings either as (a) payment for shipments in excess of guaranteed levels, if and to the extent the pipeline system will have the necessary capacity for shipments in excess of guaranteed levels, or (b) when shipping rights expire unused over the contractual make-up period.

Revenues

Revenues for the six months ended June 30, 2015, were $173.2 million, a $11.2 million increase compared to the six months ended June 30, 2014. This is due principally to the effect of annual tariff increases and increased pipeline shipments largely due to increased volumes from the New Mexico gathering system expansion. Overall pipeline volumes were up 25.5% for the six months ended June 30, 2015, as compared to the six months ended June 30, 2014.

Revenues from our refined product pipelines were $65.7 million, an increase of $4.9 million compared to the six months ended June 30, 2014, primarily due to increased volumes and due to increased volumes and annual tariff increases. Shipments averaged 191.3 mbpd compared to 176.3 mbpd for the six months ended June 30, 2014, largely due to lower volumes in the second quarter

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of 2014 resulting from major maintenance performed at Alon's Big Spring refinery as well as higher spot volumes on our UNEV pipeline.

Revenues from our intermediate pipelines were $14.0 million, a decrease of $0.6 million, on shipments averaging 140.6 mbpd compared to 141.0 mbpd for the six months ended June 30, 2014. Overall intermediate pipeline shipments were slightly down and revenues also decreased partially due to a $0.7 million decrease in deferred revenue realized.

Revenues from our crude pipelines were $32.1 million, an increase of $6.4 million, on shipments averaging 289.3 mbpd compared to 177.8 mbpd for the six months ended June 30, 2014. Revenues increased mainly due to $4.2 million in increased revenue from the New Mexico gathering system expansion, increased volumes from increased crude production in the Artesia Basin, and the reversal of the Roadrunner pipeline which made it possible for HFC to purchase and HEP to transport crude volumes in excess of HFC refining capacity.

Revenues from terminal, tankage and loading rack fees were $61.4 million, an increase of $0.4 million compared to the six months ended June 30, 2014. This increase is due principally to increased volumes and annual fee increases. Refined products terminalled in our facilities averaged 353.4 mbpd compared to 333.0 mbpd for the six months ended June 30, 2014, largely due to lower volumes in the second quarter of 2014 resulting from major maintenance performed at Alon's Big Spring refinery.

Operations Expense

Operations expense for the three months ended June 30, 2015, increased by $5.9 million compared to the six months ended June 30, 2014. The increase is due to a an increase in environmental remediation provisions of $3.5 million and higher project maintenance costs.

Depreciation and Amortization

Depreciation and amortization for the six months ended June 30, 2015, decreased by $1.7 million compared to the six months ended June 30, 2014. The decrease is due principally to lower accelerated tank depreciation and tank write-downs.

General and Administrative

General and administrative costs for the six months ended June 30, 2015, increased by $0.3 million compared to the six months ended June 30, 2014, due to increased professional fees.

Equity in Earnings of SLC Pipeline

Our equity in earnings of the SLC Pipeline was $1.4 million and $1.3 million for the six months ended June 30, 2015 and 2014, respectively.

Interest Expense

Interest expense for the six months ended June 30, 2015, totaled $17.8 million, a decrease of $1.0 million compared to the six months ended June 30, 2014. The decrease is primarily due to the early retirement of our 8.25% Senior Notes in March 2014 partially offset by higher interest on the amended credit agreement. Our aggregate effective interest rates were 4.0% and 4.5% for the six months ended June 30, 2015 and 2014, respectively.

Loss on Early Extinguishment of Debt

We recognized a charge of $7.7 million upon the early extinguishment of our 8.25% Senior Notes in March 2014. This charge represents the premium paid to noteholders upon their tender of an aggregate principal amount of $6.2 million and related financing costs of $1.5 million that were previously deferred.

State Income Tax

We recorded state income tax expense of $37,000 and $103,000 for the six months ended June 30, 2015 and 2014, respectively. All tax expense is solely attributable to the Texas margin tax.

LIQUIDITY AND CAPITAL RESOURCES

Overview

We have an $850 million senior secured revolving credit facility expiring in November 2018 (the “Credit Agreement”), which is available to fund capital expenditures, investments, acquisitions, distribution payments and working capital and for general partnership purposes. It is also available to fund letters of credit up to a $50 million sub-limit.

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During the six months ended June 30, 2015, we received advances totaling $254.1 million and repaid $221.1 million, resulting in a net increase of $33.0 million under the Credit Agreement and an outstanding balance of $604.0 million at June 30, 2015. We have no letters of credit outstanding under the Credit Agreement at June 30, 2015, and the available capacity under the Credit Agreement is $246.0 million at June 30, 2015.

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.

Under our registration statement filed with the 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.

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 February and May 2015, we paid regular quarterly cash distributions of $0.53 and $0.5375 on all units in an aggregate amount of $82.6 million including $18.3 million of incentive distribution payments to the general partner.

Contemporaneously with our UNEV Pipeline interest acquisition on July 12, 2012, HEP Logistics, our general partner, agreed to forego its right to incentive distributions of $1.25 million per quarter over twelve consecutive quarterly periods following the close of the transaction and up to an additional four quarters in certain circumstances.

Cash and cash equivalents increased by $7.6 million during the six months ended June 30, 2015. The cash flows provided by operating activities of $110.5 million were more than the sum of cash flows used for financing and investing activities of $53.6 million and $49.3 million, respectively. Working capital increased by $10.1 million to a positive $13.2 million at June 30, 2015, from $3.1 million at December 31, 2014.

Cash Flows—Operating Activities

Cash flows from operating activities increased by $18.1 million from $92.4 million for the six months ended June 30, 2014, to $110.5 million for the six months ended June 30, 2015. This increase is due principally to $15.8 million of greater cash receipts for services performed and lower interest payments of $4.7 million partially offset by increased operating expenses in the six months ended June 30, 2015, as compared to the prior year.

Cash Flows—Investing Activities

Cash flows used for investing activities were $49.3 million for the six months ended June 30, 2015, compared to $38.5 million for the six months ended June 30, 2014, an increase of $10.8 million. During the six months ended June 30, 2015 and 2014, we invested $22.9 million and $38.6 million in additions to properties and equipment, respectively. We also purchased El Dorado crude tank assets for $27.5 million in March 2015.

Cash Flows—Financing Activities

Cash flows used for financing activities were $53.6 million for the six months ended June 30, 2015, compared to $54.2 million for the six months ended June 30, 2014, a decrease of $0.6 million. During the six months ended June 30, 2015, we received $254.1 million and repaid $221.1 million in advances under the Credit Agreement. Additionally, we paid $82.6 million in regular quarterly cash distributions to our general and limited partners, $2.9 million to our noncontrolling interest and $0.2 million for the purchase of common units for recipients of our incentive grants. During the six months ended June 30, 2014, we received $477.1 million and repaid $297.1 million in advances under the Credit Agreement and paid $156.2 million to redeem the 8.25% Senior Notes. We paid $75.6 million in regular quarterly cash distributions to our general and limited partners, distributed $2.0 million to our noncontrolling interest, and paid $0.4 million for the purchase of common units for recipients of our incentive grants.

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

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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.

Each year the board of directors of Holly Logistic Services, L.L.C., our ultimate general partner ("HLS"), 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. The 2015 capital budget is comprised of $9.7 million for maintenance capital expenditures and $77.7 million for expansion capital expenditures. We expect the majority of the expansion capital budget to be invested in crude storage for HFC's El Dorado refinery, product distribution enhancements, new storage tanks, and an additional UNEV origin connection. 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.

On March 6, 2015, we completed the acquisition of an existing crude tank farm adjacent to HFC's El Dorado Refinery from an unrelated third-party for $27.5 million in cash. We recorded the assets acquired and liabilities assumed at their fair values at the date of acquisition based on preliminary valuations. Substantially all of the purchase price was allocated to properties and equipment, and no goodwill has been recorded. We expect to finalize the purchase price allocation during the third quarter of 2015. HFC is the main customer of this crude tank farm.

We have identified potential dropdown assets from HFC including the naphtha fractionation unit at HFC’s El Dorado Refinery and certain assets related to the initial phase of the expansion at HFC's Woods Cross Refinery.

We expect that our currently planned 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.

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, 2016, and ending in June 2032, subject to certain limitations.

Credit Agreement

In April 2015, we amended our senior secured revolving credit facility (the “Credit Agreement”) increasing the size of the credit facility from $650 million to $850 million. The Credit Agreement is available to fund capital expenditures, investments, acquisitions, distribution payments and working capital and for general partnership purposes. It is also available to fund letters of credit up to a $50 million sub-limit.

Our obligations under the Credit Agreement are collateralized by substantially all of our assets. Indebtedness under the Credit Agreement involves recourse to HEP Logistics Holdings, L.P. (“HEP Logistics”), our general partner, and is guaranteed by our material wholly-owned subsidiaries. Any recourse to HEP Logistics would be limited to the extent of its assets, which other than its investment in us, are not significant. We may prepay all loans at any time without penalty, except for payment of certain breakage and related costs.

The Credit Agreement imposes certain requirements on us which we are currently in compliance with, including: a prohibition against distribution to unitholders if, before or after the distribution, a potential default or an event of default as defined in the agreement would occur; limitations on our ability to incur debt, make loans, acquire other companies, change the nature of our business, enter into a merger or consolidation, or sell assets; and covenants that require maintenance of a specified EBITDA to interest expense ratio, total debt to EBITDA ratio and senior debt to EBITDA ratio. If an event of default exists under the Credit Agreement, the lenders will be able to accelerate the maturity of the debt and exercise other rights and remedies.

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Senior Notes

We have $300.0 million in aggregate principal amount outstanding of 6.5% senior notes (the "6.5% Senior Notes") maturing March 2020. The 6.5% Senior Notes are unsecured and impose certain restrictive covenants, with which we are currently in compliance, 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. At any time when the 6.5% 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 6.5% Senior Notes.

Indebtedness under the 6.5% Senior Notes involves recourse to HEP Logistics, our general partner, and is guaranteed by our wholly-owned subsidiaries. However, any recourse to HEP Logistics would be limited to the extent of its assets, which other than its investment in us, are not significant.

Long-term Debt

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



	June 30, 2015			December 31, 2014
	(In thousands)
Credit Agreement	$	604,000		$	571,000

6.5% Senior Notes
Principal	300,000			300,000
Unamortized discount	(3,095		)	(3,421		)
	296,905			296,579

Total long-term debt	$	900,905		$	867,579

See “Risk Management” for a discussion of our interest rate swaps.

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 six months ended June 30, 2015 and 2014. Historically, the PPI has increased an average of 2.3% annually over the past five calendar years.

The substantial majority of our revenues are generated under long-term contracts that provide for increases in our rates and minimum revenue guarantees annually for increases in the PPI. Certain of these contracts have provisions that limit the level of annual PPI percentage rate increases. Although the recent PPI increase may not be indicative of additional increases to be realized in the future, a significant and prolonged period of high 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. We believe our operations are in substantial compliance with applicable environmental laws and regulations. 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.

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

There are environmental remediation projects that are currently in progress that relate to certain assets acquired from HFC. Certain of these projects were underway prior to our purchase and represent liabilities of HFC as the obligation for future remediation activities was retained by HFC. At June 30, 2015, we have an accrual of $8.6 million that relates 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.

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, 2014. 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. There have been no changes to these policies in 2015. 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.

New Accounting Pronouncements

Revenue Recognition

Debt Issuance Costs

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RISK MANAGEMENT

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

As of June 30, 2015, we have three interest rate swaps, designated as a cash flow hedge, that hedge our exposure to the cash flow risk caused by the effects of LIBOR changes on $305.0 million of Credit Agreement advances. Our first interest rate swap effectively converts $155.0 million of our LIBOR based debt to fixed rate debt having an interest rate of 0.99% plus an applicable margin of 2.00% as of June 30, 2015, which equaled an effective interest rate of 2.99%. This swap contract matures in February 2016. Also, we have two similar interest rate swaps with identical terms which effectively convert $150.0 million of our LIBOR based debt to fixed rate debt having an interest rate of 0.74% plus an applicable margin of 2.00% as of June 30, 2015, which equaled an effective interest rate of 2.74%. Both of these swap contracts mature in July 2017.

We review publicly available information on our counterparties in order to monitor their financial stability and assess their ongoing ability to honor their commitments under the interest rate swap contracts. These counterparties are large financial institutions.

Furthermore, we have not experienced, nor do we expect to experience, any difficulty in the counterparties honoring their respective commitments.

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

At June 30, 2015, we had an outstanding principal balance on our 6.5% Senior Notes of $300 million. A change in interest rates generally would affect the fair value of the Senior Notes, but not our earnings or cash flows. At June 30, 2015, the fair value of our 6.5% Senior Notes was $295.9 million. We estimate a hypothetical 10% change in the yield-to-maturity applicable to the 6.5% Senior Notes at June 30, 2015, would result in a change of approximately $8.2 million in the fair value of the underlying notes.

For the variable rate Credit Agreement, changes in interest rates would affect cash flows, but not the fair value. At June 30, 2015, borrowings outstanding under the Credit Agreement were $604.0 million. By means of our cash flow hedges, we have effectively converted the variable rate on $305.0 million of outstanding borrowings to a fixed rate. For the remaining unhedged Credit Agreement borrowings of $299.0 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, 2014. We utilize derivative instruments to hedge our interest rate exposure, as discussed under “Risk Management.”

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.


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 Securities and Exchange Commission’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 June 30, 2015, at a reasonable level of assurance.

(b) Changes in internal control over financial reporting

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

We are a party to various legal and regulatory proceedings, which we believe will not have a material adverse impact on our financial condition, results of operations or cash flows.


Item 1A.	Risk Factors

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, 2014, except for the additional risk factor described below. In addition to the other information set forth in this quarterly report, you should consider carefully the factors discussed below and in our 2014 Form 10-K, which could materially affect our business, financial condition or future results. The risks described in this quarterly report and in our 2014 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 tax treatment of publicly traded partnerships or an investment in our common units could be subject to potential legislative, judicial or administrative changes and differing interpretations, possibly applied on a retroactive basis.

The present U.S. 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 or differing interpretations at any time. For example, the Obama administration's budget proposal for fiscal year 2016 recommends that certain publicly traded partnerships earning income from activities related to fossil fuels be taxed as corporations beginning in 2021. From time to time, members of Congress propose and consider such substantive changes to the existing federal income tax laws that affect publicly traded partnerships. If successful, the Obama administration's proposal or other similar proposals could eliminate the qualifying income exception to the treatment of all publicly traded partnerships as corporations, upon which we rely for our treatment as a partnership for U.S. federal income tax purposes.

In addition, the IRS, on May 5, 2015, issued proposed regulations concerning which activities give rise to qualifying income within the meaning of Section 7704 of the Internal Revenue Code. We do not believe the proposed regulations affect our ability to qualify as a publicly traded partnership. However, finalized regulations could modify the amount of our gross income that we are able to treat as qualifying income for the purposes of the qualifying income requirement.

Any modification to the U.S. federal income tax laws may be applied retroactively and could make it more difficult or impossible for us to meet the exception for certain publicly traded partnerships to be treated as partnerships for U.S. federal income tax purposes. We are unable to predict whether any of these changes or other proposals will ultimately be enacted. Any such changes could negatively impact the value of an investment in our common units.

Our partnership agreement provides that if a law is enacted or existing law is modified or interpreted in a manner that subjects us to taxation as a corporation or otherwise subjects us to entity-level taxation for federal income tax purposes, the minimum quarterly distribution and the target distribution amounts may be adjusted to reflect the impact of that law on us.


Item 6.	Exhibits

The Exhibit Index on page 40 of this Quarterly Report on Form 10-Q lists the exhibits that are filed or furnished, as applicable, as part of the Quarterly Report on Form 10-Q.

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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: August 5, 2015		/s/ Douglas S. Aron
		Douglas S. Aron
		Executive Vice President and Chief Financial Officer (Principal Financial Officer)

Date: August 5, 2015		/s/ Kenneth P. Norwood
		Kenneth P. Norwood
		Vice President and Controller (Principal Accounting Officer)

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Exhibit Index



Exhibit Number		Description

3.1		First Amended and Restated Agreement of Limited Partnership of Holly Energy Partners, L.P. (incorporated by reference to Exhibit 3.1 of Registrant's Quarterly Report on Form 10-Q for its quarterly period ended June 30, 2004, File No. 1-32225).
3.2		Amendment No. 1 to the First Amended and Restated Agreement of Limited Partnership of Holly Energy Partners, L.P., dated February 28, 2005 (incorporated by reference to Exhibit 3.1 of Registrant's Form 8-K Current Report dated February 28, 2005, File No. 1-32225).
3.3		Amendment No. 2 to the First Amended and Restated Agreement of Limited Partnership of Holly Energy Partners, L.P., as amended, dated July 6, 2005 (incorporated by reference to Exhibit 3.1 of Registrant's Form 8-K Current Report dated July 6, 2005, File No. 1-32225).
3.4		Amendment No. 3 to First Amended and Restated Agreement of Limited Partnership of Holly Energy Partners, L.P., dated April 11, 2008 (incorporated by reference to Exhibit 4.1 of Registrant's Current Report on Form 8-K dated April 15, 2008, File No. 1-32225).
3.5		Amendment No. 4 to First Amended and Restated Agreement of Limited Partnership of Holly Energy Partners, L.P., dated January 16, 2013 (incorporated by reference to Exhibit 3.1 of Registrant's Current Report on Form 8-K dated January 16, 2013, File No. 1-32225).
3.6		Limited Partial Waiver of Incentive Distribution Rights under the First Amended and Restated Agreement of Limited Partnership of Holly Energy Partners, L.P., dated as of July 12, 2012 (incorporated by reference to Exhibit 3.1 of Registrant's Current Report on Form 8-K dated July 12, 2012, File No. 1-32225).
3.7		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 its quarterly period ended June 30, 2004, File No. 1-32225).
3.8		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).
3.9		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).
3.10		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 dated May 3, 2011, File No. 1-32225).
3.11		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+		Mortgage, Line of Credit Mortgage and Deed of Trust (with Security Agreement and Financing Statement), dated May 29, 2015, by HEP Refining, L.L.C. for the benefit of HollyFrontier Corporation.
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**		The following financial information from Holly Energy Partners, L.P.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2015, formatted in XBRL (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.



+	Filed herewith.
++	Furnished herewith.
**	Filed electronically herewith.

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HOLLY ENERGY PARTNERS LP Reports

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