10-Q 1 hep3-31x201210q.htm HEP 3-31-2012 10Q


UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 ______________________________________________________________________________________
FORM 10-Q
 ______________________________________________________________________________________
ý
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 2012
OR

¨
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from ____________ to _____________                    
Commission File Number: 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 April 27, 2012 was 27,361,124.



HOLLY ENERGY PARTNERS, L.P.
INDEX
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Item 1.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Item 2.
 
 
 
 
 
Item 3.
 
 
 
 
 
Item 4.
 
 
 
 
 
 
 
Item 1.
 
 
 
 
 
Item 1A.
 
 
 
 
 
Item 5.
 
 
 
 
 
Item 6.
 
 
 
 
 
 
 
 
 
 
 
 

- 2 -


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,” “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. Such 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 successfully purchase and integrate additional operations in the future;
•
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, 2011 in “Risk Factors” and in this Form 10-Q in “Management’s Discussion and Analysis of Financial Condition and Results of Operations.” 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.


- 3 -

PART I. FINANCIAL INFORMATION


Item 1.
Financial Statements

Holly Energy Partners, L.P.
Consolidated Balance Sheets 
 
 
March 31, 2012 (Unaudited)
 
December 31, 2011
 
 
(In thousands, except unit data)
ASSETS
 
 
 
 
Current assets:
 
 
 
 
Cash and cash equivalents
 
$
12,402

 
$
3,269

Accounts receivable:
 
 
 
 
Trade
 
3,884

 
3,055

Affiliates
 
30,900

 
31,016

 
 
34,784

 
34,071

Prepaid and other current assets
 
2,403

 
2,644

Total current assets
 
49,589

 
39,984

 
 
 
 
 
Properties and equipment, net
 
534,244

 
536,425

Transportation agreements, net
 
99,806

 
101,543

Goodwill
 
256,498

 
256,498

Investment in SLC Pipeline
 
25,382

 
25,302

Other assets
 
7,319

 
7,204

Total assets
 
$
972,838

 
$
966,956

 
 
 
 
 
LIABILITIES AND PARTNERS’ EQUITY
 
 
 
 
Current liabilities:
 
 
 
 
Accounts payable:
 
 
 
 
Trade
 
$
6,368

 
$
6,107

Affiliates
 
6,225

 
5,299

 
 
12,593

 
11,406

 
 
 
 
 
Accrued interest
 
1,808

 
8,280

Deferred revenue
 
3,440

 
4,032

Accrued property taxes
 
1,801

 
2,196

Other current liabilities
 
1,893

 
1,777

Current portion of long-term debt
 
27,239

 
—

Total current liabilities
 
48,774

 
27,691

 
 
 
 
 
Long-term debt, net of current portion
 
597,956

 
605,888

Other long-term liabilities
 
4,635

 
4,000

 
 
 
 
 
Partners’ equity:
 
 
 
 
Common unitholders (27,361,124 units issued and outstanding
    at March 31, 2012 and December 31, 2011)
 
473,931

 
482,509

General partner interest (2% interest)
 
(146,914
)
 
(146,668
)
Accumulated other comprehensive loss
 
(5,544
)
 
(6,464
)
Total partners’ equity
 
321,473

 
329,377

Total liabilities and partners’ equity
 
$
972,838

 
$
966,956


See accompanying notes.

- 4 -

Holly Energy Partners, L.P.
Consolidated Statements of Income
(Unaudited)
 
 
 
Three Months Ended March 31,
 
 
 
2012
 
2011
 
 
 
(In thousands, except per unit data)
Revenues:
 
 
 
 
 
Affiliates
 
$
52,793

 
$
34,107

 
Third parties
 
10,722

 
10,910

 
 
 
63,515

 
45,017

 
Operating costs and expenses:
 
 
 
 
 
Operations
 
16,988

 
12,796

 
Depreciation and amortization
 
10,264

 
7,640

 
General and administrative
 
2,039

 
1,363

 
 
 
29,291

 
21,799

 
Operating income
 
34,224

 
23,218

 
 
 
 
 
 
 
Other income (expense):
 
 
 
 
 
Equity in earnings of SLC Pipeline
 
831

 
740

 
Interest expense
 
(10,405
)
 
(8,549
)
 
Loss on early extinguishment of debt
 
(2,596
)
 
—

 
Other expense
 
—

 
(12
)
 
 
 
(12,170
)
 
(7,821
)
 
Income before income taxes
 
22,054

 
15,397

 
State income tax expense
 
(75
)
 
(228
)
 
Net income
 
21,979

 
15,169

 
Less general partner interest in net income, including incentive distributions
 
5,507

 
3,562

 
Limited partners’ interest in net income
 
$
16,472

 
$
11,607

 
Limited partners’ per unit interest in earnings—basic and diluted:
 
$
0.60

 
$
0.53

 
Weighted average limited partners’ units outstanding
 
27,361

 
22,079

 

See accompanying notes.


- 5 -

Holly Energy Partners, L.P.
Consolidated Statements of Comprehensive Income
(Unaudited)

 
 
Three Months Ended March 31,
 
 
 
2012
 
2011
 
 
 
(In thousands)
 
 
 
 
 
 
Net income
 
$
21,979

 
$
15,169

 
 
 
 
 
 
 
Other comprehensive income (loss):
 
 
 
 
 
Change in fair value of cash flow hedge
 
(354
)
 
1,283

 
Amortization of unrealized loss attributable to discontinued cash flow hedge
 
1,274

 
—

 
Other comprehensive income
 
920

 
1,283

 
Comprehensive income
 
$
22,899

 
$
16,452

 

See accompanying notes.


- 6 -

Holly Energy Partners, L.P.
Consolidated Statements of Cash Flows
(Unaudited)
 
 
 
Three Months Ended March 31,
 
 
2012
 
2011
 
 
(In thousands)
Cash flows from operating activities
 
 
 
 
Net income
 
$
21,979

 
$
15,169

Adjustments to reconcile net income to net cash provided by operating activities:
 
 
 
 
Depreciation and amortization
 
10,264

 
7,640

Equity in earnings of SLC Pipeline, net of distributions
 
(81
)
 
(365
)
Amortization of restricted and performance units
 
943

 
670

(Increase) decrease in current assets:
 
 
 
 
Accounts receivable—trade
 
(829
)
 
442

Accounts receivable—affiliates
 
(347
)
 
(1,409
)
Prepaid and other current assets
 
307

 
229

Increase (decrease) in current liabilities:
 
 
 
 
Accounts payable—trade
 
(493
)
 
(356
)
Accounts payable—affiliates
 
926

 
443

Accrued interest
 
(6,472
)
 
(5,976
)
Deferred revenue
 
(592
)
 
(1,104
)
Accrued property taxes
 
(395
)
 
(252
)
Other current liabilities
 
131

 
(183
)
Other, net
 
2,882

 
274

Net cash provided by operating activities
 
28,223

 
15,222

 
 
 
 
 
Cash flows from investing activities
 
 
 
 
Additions to properties and equipment
 
(6,327
)
 
(11,475
)
 
 
 
 
 
Cash flows from financing activities
 
 
 
 
Borrowings under credit agreement
 
36,000

 
30,000

Repayments of credit agreement borrowings
 
(81,000
)
 
(7,000
)
Proceeds from issuance of senior notes
 
294,750

 
—

Repayments of senior notes
 
(157,761
)
 
—

Repayment of promissory notes
 
(72,900
)
 
—

Distributions to HEP unitholders
 
(29,716
)
 
(22,205
)
Purchase of units for incentive grants
 
(1,283
)
 
(399
)
Deferred financing costs
 
(1,123
)
 
(3,044
)
Other
 
270

 
—

Net cash used for financing activities
 
(12,763
)
 
(2,648
)
 
 
 
 
 
Cash and cash equivalents
 
 
 
 
Increase for the period
 
9,133

 
1,099

Beginning of period
 
3,269

 
403

End of period
 
$
12,402

 
$
1,502


See accompanying notes.


- 7 -

Holly Energy Partners, L.P.
Consolidated Statement of Partners’ Equity
(Unaudited)
 
 
 
Common
Units
 
General
Partner
Interest
 
Accumulated
Other
Comprehensive
Loss
 
Total
 
 
(In thousands)
 
 
 
 
 
 
 
 
 
Balance December 31, 2011
 
$
482,509

 
$
(146,668
)
 
$
(6,464
)
 
$
329,377

 
 
 
 
 
 
 
 
 
Distributions to unitholders
 
(24,213
)
 
(5,503
)
 
—

 
(29,716
)
Purchase of units for incentive grants
 
(2,037
)
 
—

 
—

 
(2,037
)
Amortization of restricted and performance units
 
943

 
—

 
—

 
943

Other
 
—

 
7

 
—

 
7

Net income
 
16,729

 
5,250

 
—

 
21,979

Other comprehensive income
 
—

 
—

 
920

 
920

Balance March 31, 2012
 
$
473,931

 
$
(146,914
)
 
$
(5,544
)
 
$
321,473


See accompanying notes.


- 8 -

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, currently 42% owned (including the 2% general partner interest) by HollyFrontier Corporation (“HFC”) and its subsidiaries. In these consolidated financial statements, the words “we,” “our,” “ours” and “us” refer to HEP unless the context otherwise indicates.

We operate in one operating segment—the operation of petroleum product and crude oil pipelines and terminals, tankage and loading rack facilities.

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 25% joint venture interest in a 95-mile intrastate crude oil pipeline system (the “SLC Pipeline”) that serves refineries in the Salt Lake City 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.

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, 2011. 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, 2012.

New Accounting Pronouncements

Presentation of Comprehensive Income
Effective January 1, 2012, we adopted the accounting standard update that requires the presentation of net income and other comprehensive income in one continuous statement or in two separate, but consecutive, statements and eliminated the option to present the components of other comprehensive income in the statement of partners' equity.

Intangibles-Goodwill and Other: Testing Goodwill for Impairment
Effective January 1, 2012, we adopted the accounting standard update that allows entities an option to first assess qualitative factors to determine whether it is necessary to perform the two-step quantitative goodwill impairment test. Under this option, we  no longer are required to calculate the fair value of a reporting unit unless we determine, based on that qualitative assessment, that it is more likely than not that the reporting unit's fair value is less than its carrying amount. The adoption of this accounting standard did not have an impact on our financial condition, results of operations and cash flows.


Note 2:
Acquisitions

Legacy Frontier Pipeline and Tankage Asset Transaction

On November 9, 2011, we acquired from HFC certain tankage, loading rack and crude receiving assets located at HFC’s El Dorado and Cheyenne refineries. We paid non-cash consideration consisting of promissory notes with an aggregate principal amount of $150.0 million and 3,807,615 of our common units. In connection with the transaction, we entered into 15-year throughput agreements with HFC that result in minimum annual revenue commitments to us of $46.9 million. We are a consolidated variable interest entity of HFC, and accordingly we accounted for this transaction as a business combination between entities under common control and therefore, we have recorded this transfer at HFC's cost basis.

We recorded properties and equipment of $88.1 million, goodwill of $207.4 million and a non-cash capital contribution of $295.5 million, representing HFC's cost basis in the acquired assets. On November 9, 2011, we recorded a $150.0 million liability

- 9 -

HOLLY ENERGY PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited) Continued


representing the promissory notes issued to HFC at the time of the closing of this transaction and a corresponding decrease to HFC's non-cash contribution.

Assuming this acquisition had occurred on January 1, 2011 and our throughput agreements with HFC were in effect at that time, pro forma revenues, net income and earnings per unit for the three months ended March 31, 2011 are estimated to have been $56.9 million, $23.3 million and $0.74, respectively.


Note 3:
Financial Instruments

Our financial instruments consist of cash and cash equivalents, accounts receivable, accounts payable, debt and an interest rate swap. 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 fixed interest rate senior notes.

Fair value measurements are derived using inputs (assumptions that market participants would use in pricing an asset or liability) including assumptions about risk. GAAP categorizes inputs used in fair value measurements into three broad levels as follows:
•
(Level 1) Quoted prices in active markets for identical assets or liabilities.
•
(Level 2) Observable inputs other than quoted prices included in Level 1, such as quoted prices for similar assets and liabilities in active markets, similar assets and liabilities in markets that are not active or can be corroborated by observable market data.
•
(Level 3) Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. This includes valuation techniques that involve significant unobservable inputs.

The carrying amounts and estimated fair values of our senior notes and interest rate swap at March 31, 2012 and December 31, 2011 were as follows:
 
 
 
 
March 31, 2012
 
December 31, 2011
Financial Instrument
 
Fair Value Input Level
 
Carrying
Amount
 
Fair Value
 
Carrying
Amount
 
Fair Value
 
 
 
 
(In thousands)
Senior notes:
 
 
 
 
 
 
 
 
 
 
6.25% senior notes
 
Level 2
 
$
27,239

 
$
27,562

 
$
184,895

 
$
186,850

6.5% senior notes
 
Level 2
 
294,786

 
305,250

 
—

 
—

8.25% senior notes
 
Level 2
 
148,170

 
161,250

 
148,093

 
157,500

 
 
 
 
470,195

 
494,062

 
332,988

 
344,350

 
 
 
 
 
 
 
 
 
 
 
Interest rate swap
 
Level 2
 
(873
)
 
(873
)
 
(520
)
 
(520
)
 
 
 
 
$
469,322

 
$
493,189

 
$
332,468

 
$
343,830


Level 2 Financial Instruments

Our senior notes and interest rate swap are measured and recorded 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 instruments. With respect to our interest rate swap, the fair value 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 7 for additional information on these instruments.


- 10 -

HOLLY ENERGY PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited) Continued



Note 4:
Properties and Equipment 

The carrying amounts of our properties and equipment are as follows:
 
 
March 31,
2012
 
December 31,
2011
 
 
(In thousands)
 
 
 
 
 
Pipelines and terminals
 
$
633,934

 
$
633,095

Land and right of way
 
27,149

 
27,149

Other
 
16,728

 
16,507

Construction in progress
 
19,638

 
14,419

 
 
697,449

 
691,170

Less accumulated depreciation
 
163,205

 
154,745

 
 
$
534,244

 
$
536,425


We capitalized $0.1 million and $0.2 million in interest related to construction projects during the three months ended March 31, 2012 and 2011, respectively.


Note 5:
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 (at which time we were not a consolidated variable interest entity of HFC) that are based on the respective agreement's expected future earnings contribution. 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:
 
 
March 31,
2012
 
December 31,
2011
 
 
(In thousands)
 
 
 
 
 
Alon transportation agreement
 
$
59,933

 
$
59,933

HFC transportation agreement
 
74,231

 
74,231

 
 
134,164

 
134,164

Less accumulated amortization
 
34,358

 
32,621

 
 
$
99,806

 
$
101,543


We have additional transportation agreements with HFC that relate to assets contributed to us or acquired from HFC consisting of pipeline, terminal and tankage assets. 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 6:
Employees, Retirement and Incentive Plans

Employees who provide direct services to us are employed by Holly Logistic Services, L.L.C., an HFC subsidiary. 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 $1.5 million and $0.7 million for the three months ended March 31, 2012 and 2011, respectively.

We have an incentive plan (“Long-Term Incentive Plan”) for employees, consultants and non-employee directors who perform services for us. The Long-Term Incentive Plan consists of four components: restricted units, performance units, unit options and unit appreciation rights.

- 11 -

HOLLY ENERGY PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited) Continued



As of March 31, 2012, we have two types of equity-based compensation, which are described below. The compensation cost charged against income was $0.9 million and $0.7 million for the three months ended March 31, 2012 and 2011, respectively. We currently purchase units in the open market instead of issuing new units for settlement of all unit awards under our Long-Term Incentive Plan. On April 25, 2012 our unitholders approved an amendment and restatement of our Long-Term Incentive Plan, which among other things, increased the units authorized to be granted under our Long-Term Incentive Plan from 350,000 to 1,250,000. Upon such approval, the amendment and restatement of the Long-Term Incentive Plan was effective February 10, 2012, which is the date the amendment and restatement was approved by our board of directors. As a result of such amendment and restatement, 1,250,000 units are authorized to be granted under the Long-Term Incentive Plan, of which 922,221 have not yet been granted, assuming no forfeitures of the unvested units and full achievement of goals for the performance units already granted.

Restricted Units
Under our Long-Term Incentive Plan, we grant restricted units to selected employees and directors who perform services for us, with most awards vesting over a period of one to three years. Although full ownership of the units does not transfer to the recipients until the units vest, the recipients have distribution and voting rights on these units from the date of grant. The fair value of each restricted unit award is measured at the market price as of the date of grant and is amortized over the vesting period.

A summary of restricted unit activity and changes during the three months ended March 31, 2012 is presented below:
 
Restricted Units
 
Units
 
Weighted-
Average
Grant-Date
Fair Value
 
Weighted-
Average
Remaining
Contractual
Term
 
Aggregate
Intrinsic
Value
($000)
Outstanding at January 1, 2012 (nonvested)
 
29,536

 
$
50.45

 
 
 
 
Granted
 
38,508

 
61.21

 
 
 
 
Vesting and transfer of full ownership to recipients
 
(21,240
)
 
52.25

 
 
 
 
Outstanding at March 31, 2012 (nonvested)
 
46,804

 
$
58.49

 
1.4 years
 
$
2,857


The fair value of restricted units that were vested and transferred to recipients during the three months ended March 31, 2012 and 2011 were $1.1 million and $1.0 million, respectively. As of March 31, 2012, there was $1.9 million of total unrecognized compensation expense related to nonvested restricted unit grants which is expected to be recognized over a weighted-average period of 1.4 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 March 31, 2012, estimated share payouts for outstanding nonvested performance unit awards were approximately 110%.

We granted 5,718 performance units to certain officers on March 31, 2012. These units will vest over a three-year performance period ending December 31, 2014 and are payable in HEP common units. The number of units actually earned will be based on the growth of our distributable cash flow per common unit over the performance period, and can range from 50% to 150% of the 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 that the performance units are granted. The fair value of these performance units is based on the grant date closing unit price of $61.21 and will apply to the number of units ultimately awarded.

A summary of performance unit activity and changes during the three months ended March 31, 2012 is presented below:

- 12 -

HOLLY ENERGY PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited) Continued


Performance Units
 
Payable
In Units
Outstanding at January 1, 2012 (nonvested)
 
42,991

Granted
 
5,718

Vesting and transfer of common units to recipients
 
(21,460
)
Outstanding at March 31, 2012 (nonvested)
 
27,249


The fair value of performance units vested and transferred to recipients during the three months ended March 31, 2012 and 2011 was $0.5 million and $0.6 million, respectively. Based on the weighted average fair value at March 31, 2012 of $52.11, there was $0.9 million of total unrecognized compensation expense related to nonvested performance units, which is expected to be recognized over a weighted-average period of 1.7 years.

During the three months ended March 31, 2012, we paid $1.3 million for the purchase of our common units in the open market for the issuance and settlement of all unit awards under our Long-Term Incentive Plan.


Note 7:
Debt

Credit Agreement
We have a $375 million senior secured revolving credit facility expiring in February 2016 (the “Credit Agreement”) that is available to fund capital expenditures, investments, acquisitions, distribution payments and working capital and for general partnership purposes. Also, it is available to fund letters of credit up to a $50 million sub-limit and to fund distributions to unitholders up to a $30 million sub-limit. In February 2012 we amended our previous credit agreements increasing the size of the credit facility from $275 million to $375 million.

During the three months ended March 31, 2012, we received advances totaling $36.0 million and repaid $81.0 million, resulting in net repayments of $45.0 million under the Credit Agreement and an outstanding balance of $155.0 million at March 31, 2012.

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 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 subject to and 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 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
In March 2012, we issued $300.0 million in aggregate principal amount outstanding of 6.5% senior notes maturing March 1, 2020 (the "6.5% Senior Notes"). The $294.8 million in net proceeds from the issuance were used to fund $157.8 million aggregate principal amount of 6.25% Senior Notes tendered pursuant to a cash tender offer and consent solicitation announced in February 2012, to repay $72.9 million in Promissory Notes due to HFC as discussed below, related fees, expenses and accrued interest in connection with these transactions and to repay borrowings under the Credit Agreement.

In April 2012, we called for redemption $27.2 million aggregate principal amount of 6.25% senior notes that remained outstanding following the cash tender offer and consent solicitation.

In March 2010, we issued $150.0 million in aggregate principal amount outstanding of 8.25% senior notes (the "8.25% Senior Notes") maturing March 15, 2018. A portion of the $147.5 million in net proceeds from the issuance was used to fund our $93.0 million purchase of the Tulsa and Lovington storage assets from HFC on March 31, 2010. Additionally, we used a portion to repay $42.0 million in outstanding Credit Agreement borrowings, with the remaining proceeds available for general partnership

- 13 -

HOLLY ENERGY PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited) Continued


purposes, including working capital and capital expenditures.

The 6.5% Senior Notes and 8.25% Senior Notes (collectively, the “Senior Notes”) are unsecured and impose certain restrictive covenants, which we are subject to and currently in compliance with, 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 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 under the Senior Notes.

Indebtedness under the Senior Notes is recourse to HEP Logistics, our general partner, and 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.

Promissory Notes
In November 2011, we issued senior unsecured promissory notes to HFC (the “Promissory Notes”) having an aggregate principal amount of $150 million to finance a portion of our November 9, 2011 acquisition of certain tankage, loading rack and crude receiving assets located at HFC's El Dorado and Cheyenne refineries (see Note 2). In December 2011, we repaid $77.1 million of outstanding principal using proceeds received in our December 2011 common unit offering and existing cash. We repaid the remaining $72.9 million balance in March 2012.

Long-term Debt
The carrying amounts of our long-term debt are as follows: 
 
 
March 31,
2012
 
December 31,
2011
 
 
(In thousands)
Credit Agreement
 
$
155,000

 
$
200,000

6.5% Senior Notes
 
 
 
 
Principal
 
300,000

 
—

Unamortized discount
 
(5,214
)
 
—

 
 
294,786

 
—

6.25% Senior Notes
 
 
 
 
Principal
 
27,254

 
185,000

Unamortized net discount
 
(15
)
 
(105
)
 
 
27,239

 
184,895

8.25% Senior Notes
 
 
 
 
Principal
 
150,000

 
150,000

Unamortized discount
 
(1,830
)
 
(1,907
)
 
 
148,170

 
148,093

 
 
 
 
 
 Promissory Notes
 
—

 
72,900

 
 
 
 
 
Total debt
 
625,195

 
605,888

Less current portion of long-term debt
 
27,239

 
—

 
 
 
 
 
Total long-term debt
 
$
597,956

 
$
605,888


Interest Rate Risk Management
We use interest rate swaps (derivative instruments) to manage our exposure to interest rate risk.

As of March 31, 2012, we have an interest rate swap that hedges our exposure to the cash flow risk caused by the effects of LIBOR changes on a $155.0 million Credit Agreement advance. This 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, currently 2.25%, which equaled an effective interest rate of 3.24% as of March 31, 2012. This swap contract matures in February 2016.


- 14 -

HOLLY ENERGY PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited) Continued


We have designated this interest rate swap as a cash flow hedge. Based on our assessment of effectiveness using the change in variable cash flows method, we have determined that this interest rate swap is effective in offsetting the variability in interest payments on $155.0 million of our variable rate debt resulting from changes in LIBOR. Under hedge accounting, we adjust our cash flow hedge on a quarterly basis to its fair value with the offsetting fair value adjustment to accumulated other comprehensive 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 swap against the expected future interest payments on $155.0 million of our variable rate debt. Any ineffectiveness is reclassified from accumulated other comprehensive loss to interest expense. As of March 31, 2012, we had no ineffectiveness on our cash flow hedge.

At March 31, 2012, we have an accumulated other comprehensive loss of $5.5 million that relates to our current and previous cash flow hedging instruments. Of this amount, $4.7 million represents an unrecognized loss that is attributable to a cash flow hedge terminated in December 2011 and represents the application of hedge accounting prior to termination. This amount will be amortized as a charge to interest expense through February 2013, the remaining term of the terminated swap contract. The remaining $0.8 million amount will be effectively 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 swap is as follows:

Derivative Instrument
 
Balance Sheet
Location
 
Fair Value
 
Location of Offsetting
Balance
 
Offsetting
Amount
 
 
(In thousands)
March 31, 2012
 
 
 
 
 
 
 
 
Interest rate swap designated as cash flow hedging instrument:
 
 
 
 
 
 
Variable-to-fixed interest rate swap contract ($155 million of LIBOR based debt interest)
 
Other long-term
    liabilities
 
$
873

 
Accumulated other
    comprehensive loss
 
$
873

December 31, 2011
 
 
 
 
 
 
 
 
Interest rate swap designated as cash flow hedging instrument:
 
 
 
 
 
 
Variable-to-fixed interest rate swap contract ($155 million of LIBOR based debt interest)
 
Other long-term
    liabilities
 
$
520

 
Accumulated other
    comprehensive loss
 
$
520



Interest Expense and Other Debt Information
Interest expense consists of the following components: 
 
 
Three Months Ended March 31,
 
 
2012
 
2011
 
 
(In thousands)
Interest on outstanding debt:
 
 
 
 
Credit Agreement, net of interest on interest rate swap
 
$
1,575

 
$
2,365

6.5% Senior Notes
 
1,083

 
—

6.25% Senior Notes
 
2,370

 
2,891

8.25% Senior Notes
 
3,094

 
3,094

       Promissory Notes
 
543

 
—

Amortization of discount and deferred debt issuance costs
 
1,645

 
290

Commitment fees
 
167

 
113

Total interest incurred
 
10,477

 
8,753

Less capitalized interest
 
72

 
204

Net interest expense
 
$
10,405

 
$
8,549

Cash paid for interest
 
$
15,292

 
$
14,439


We recognized a charge of $2.6 million upon the early extinguishment of certain long-term debt for the three months ended March 31, 2012. This charge represents the premium paid to our 6.25% senior note holders upon their tender of an aggregate principal amount of $157.8 million and related net discount.


- 15 -

HOLLY ENERGY PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited) Continued



Note 8:
Significant Customers

All revenues are domestic revenues, of which 96% 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 March 31,
 
 
 
2012
 
2011
 
HFC
 
83
%
 
76
%
 
Alon
 
13
%
 
20
%
 


Note 9:
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 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 1, based on the Producer Price Index (“PPI”) or Federal Energy Regulatory Commission (“FERC”) index. As of March 31, 2012, these agreements with HFC will result in minimum annualized payments to us of $191.8 million.

If HFC fails to meet its minimum volume commitments under the agreements in any quarter, it will be required to pay us in cash the amount of any shortfall 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 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 for the provision by HFC or its affiliates of various general and administrative services to us, currently $2.3 million. This fee does not include the salaries of pipeline and terminal personnel 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 $52.8 million and $34.1 million for the three months ended March 31, 2012 and 2011, respectively.
•
HFC charged general and administrative services under the Omnibus Agreement of $0.6 million for the three months ended March 31, 2012 and 2011.
•
We reimbursed HFC for costs of employees supporting our operations of $7.6 million and $5.0 million for the three months ended March 31, 2012 and 2011, respectively.
•
We distributed $15.3 million and $9.7 million for the three months ended March 31, 2012 and 2011, respectively, to HFC as regular distributions on its common units and general partner interest, including general partner incentive distributions.
•
Accounts receivable from HFC were $30.9 million and $31.0 million at March 31, 2012 and December 31, 2011, respectively.
•
Accounts payable to HFC were $6.2 million and $5.3 million at March 31, 2012 and December 31, 2011, respectively.
•
Revenues for the three months ended March 31, 2012 include $1.7 million of shortfall payments billed in 2011, as HFC did not exceed its minimum volume commitment in any of the subsequent four quarters. Deferred revenue in the consolidated balance sheets at March 31, 2012 and December 31, 2011, includes $3.4 million and $4.0 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 $3.4 million deferred at March 31, 2012.
•
We acquired tankage and terminal assets from HFC in 2011. See Note 2 for a description of this transaction.


- 16 -

HOLLY ENERGY PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited) Continued



Note 10:
Partners’ Equity

HFC currently holds 11,097,615 of our common units and the 2% general partner interest, which together constitute a 42% 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 March 31,
 
 
 
2012
 
2011
 
 
 
(In thousands)
 
 
 
 
 
 
General partner interest in net income
 
$
336

 
$
237

 
General partner incentive distribution
 
5,171

 
3,325

 
Total general partner interest in net income
 
$
5,507

 
$
3,562

 

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 April 25, 2012, we announced our cash distribution for the first quarter of 2012 of $0.895 per unit. The distribution is payable on all common and general partner units and will be paid May 15, 2012 to all unitholders of record on May 8, 2012.

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 March 31,
 
 
 
2012
 
2011
 
 
 
(In thousands, except per unit data)
General partner interest
 
$
606

 
$
453

 
General partner incentive distribution
 
5,171

 
3,325

 
Total general partner distribution
 
5,777

 
3,778

 
Limited partner distribution
 
24,488

 
18,877

 
Total regular quarterly cash distribution
 
$
30,265

 
$
22,655

 
Cash distribution per unit applicable to limited partners
 
$
0.895

 
$
0.855

 

As a master limited partnership, we distribute our available cash, which historically has exceeded our net income because depreciation and amortization expense represents a non-cash charge against income. The result is a decline in our partners’ equity since our regular quarterly distributions have exceeded our quarterly net income. Additionally, if the assets contributed and acquired 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 of $295.6 million would have been recorded in our financial statements as increases to our properties and equipment and intangible assets instead of decreases to our partners’ equity.


Note 11:
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 wholly-owned subsidiaries (“Guarantor Subsidiaries“). These guarantees are full and unconditional.

- 17 -

HOLLY ENERGY PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited) Continued



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

Additionally, the following financial information does not include condensed consolidating statements of comprehensive income since all other comprehensive income activity relates to the Parent and not to the Guarantor Subsidiaries.

Condensed Consolidating Balance Sheet
March 31, 2012
 
Parent
 
Guarantor
Subsidiaries
 
Eliminations
 
Consolidated
 
 
(In thousands)
ASSETS
 
 
 
 
 
 
 
 
Current assets:
 
 
 
 
 
 
 
 
Cash and cash equivalents
 
$
2

 
$
12,400

 
$
—

 
$
12,402

Accounts receivable
 
—

 
34,784

 
—

 
34,784

Intercompany accounts receivable (payable)
 
107,624

 
(107,624
)
 
—

 
—

Prepaid and other current assets
 
246

 
2,157

 
—

 
2,403

Total current assets
 
107,872

 
(58,283
)
 
—

 
49,589

Properties and equipment, net
 
—

 
534,244

 
—

 
534,244

Investment in subsidiaries
 
684,863

 
—

 
(684,863
)
 
—

Transportation agreements, net
 
—

 
99,806

 
—

 
99,806

Goodwill
 
—

 
256,498

 
—

 
256,498

Investment in SLC Pipeline
 
—

 
25,382

 
—

 
25,382

Other assets
 
1,323

 
5,996

 
—

 
7,319

Total assets
 
$
794,058

 
$
863,643

 
$
(684,863
)
 
$
972,838

 
 
 
 
 
 
 
 
 
LIABILITIES AND PARTNERS’ EQUITY
 
 
 
 
 
 
 
 
Current liabilities:
 
 
 
 
 
 
 
 
Accounts payable
 
$
4

 
$
12,589

 
$
—

 
$
12,593

Accrued interest
 
1,775

 
33

 
—

 
1,808

Deferred revenue
 
—

 
3,440

 
—

 
3,440

Accrued property taxes
 
—

 
1,801

 
—

 
1,801

Other current liabilities
 
611

 
1,282

 
—

 
1,893

Current portion of long-term debt
 
27,239

 
—

 
—

 
27,239

Total current liabilities
 
29,629

 
19,145

 
—

 
48,774

Long-term debt, net of current portion
 
442,956

 
155,000

 
—

 
597,956

Other long-term liabilities
 
—

 
4,635

 
—

 
4,635

Partners’ equity
 
321,473

 
684,863

 
(684,863
)
 
321,473

Total liabilities and partners’ equity
 
$
794,058

 
$
863,643

 
$
(684,863
)
 
$
972,838



- 18 -

HOLLY ENERGY PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited) Continued


Condensed Consolidating Balance Sheet
December 31, 2011
 
Parent
 
Guarantor
Subsidiaries
 
Eliminations
 
Consolidated
 
 
(In thousands)
ASSETS
 
 
 
 
 
 
 
 
Current assets:
 
 
 
 
 
 
 
 
Cash and cash equivalents
 
$
2

 
$
3,267

 
$
—

 
$
3,269

Accounts receivable
 
—

 
34,071

 
—

 
34,071

Intercompany accounts receivable (payable)
 
17,745

 
(17,745
)
 
—

 
—

Prepaid and other current assets
 
266

 
2,378

 
—

 
2,644

Total current assets
 
18,013

 
21,971

 
—

 
39,984

Properties and equipment, net
 
—

 
536,425

 
—

 
536,425

Investment in subsidiaries
 
651,217

 
—

 
(651,217
)
 
—

Transportation agreements, net
 
—

 
101,543

 
—

 
101,543

Goodwill
 
—

 
256,498

 
—

 
256,498

Investment in SLC Pipeline
 
—

 
25,302

 
—

 
25,302

Other assets
 
1,322

 
5,882

 
—

 
7,204

Total assets
 
$
670,552

 
$
947,621

 
$
(651,217
)
 
$
966,956

 
 
 
 
 
 
 
 
 
LIABILITIES AND PARTNERS’ EQUITY
 
 
 
 
 
 
 
 
Current liabilities:
 
 
 
 
 
 
 
 
Accounts payable
 
$
—

 
$
11,406

 
$
—

 
$
11,406

Accrued interest
 
7,498

 
782

 
—

 
8,280

Deferred revenue
 
—

 
4,032

 
—

 
4,032

Accrued property taxes
 
—

 
2,196

 
—

 
2,196

Other current liabilities
 
689

 
1,088

 
—

 
1,777

Total current liabilities
 
8,187

 
19,504

 
—

 
27,691

Long-term debt
 
332,988

 
272,900

 
—

 
605,888

Other long-term liabilities
 
—

 
4,000

 
—

 
4,000

Partners’ equity
 
329,377

 
651,217

 
(651,217
)
 
329,377

Total liabilities and partners’ equity
 
$
670,552

 
$
947,621

 
$
(651,217
)
 
$
966,956



- 19 -

HOLLY ENERGY PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited) Continued


Condensed Consolidating Statement of Income
Three Months Ended March 31, 2012
 
Parent
 
Guarantor
Subsidiaries
 
Eliminations
 
Consolidated
 
 
(In thousands)
Revenues:
 
 
 
 
 
 
 
 
Affiliates
 
$
—

 
$
52,793

 
$
—

 
$
52,793

Third parties
 
—

 
10,722

 
—

 
10,722

 
 
—

 
63,515

 
—

 
63,515

Operating costs and expenses:
 
 
 
 
 
 
 
 
Operations
 
—

 
16,988

 
—

 
16,988

Depreciation and amortization
 
—

 
10,264

 
—

 
10,264

General and administrative
 
1,442

 
597

 
—

 
2,039

 
 
1,442

 
27,849

 
—

 
29,291

Operating income (loss)
 
(1,442
)
 
35,666

 
—

 
34,224

Equity in earnings of subsidiaries
 
32,725

 
—

 
(32,725
)
 
—

Equity in earnings of SLC Pipeline
 
—

 
831

 
—

 
831

Interest income (expense)
 
(6,708
)
 
(3,697
)
 
—

 
(10,405
)
Loss on early extinguishment of debt
 
(2,596
)
 
—

 
—

 
(2,596
)
 
 
23,421

 
(2,866
)
 
(32,725
)
 
(12,170
)
Income before income taxes
 
21,979

 
32,800

 
(32,725
)
 
22,054

State income tax expense
 
—

 
(75
)
 
—

 
(75
)
Net income
 
$
21,979

 
$
32,725

 
$
(32,725
)
 
$
21,979



Condensed Consolidating Statement of Income
Three Months Ended March 31, 2011
 
Parent
 
Guarantor
Subsidiaries
 
Eliminations
 
Consolidated
 
 
(In thousands)
Revenues:
 
 
 
 
 
 
 
 
Affiliates
 
$
—

 
$
34,107

 
$
—

 
$
34,107

Third parties
 
—

 
10,910

 
—

 
10,910

 
 
—

 
45,017

 
—

 
45,017

Operating costs and expenses:
 
 
 
 
 
 
 
 
Operations
 
—

 
12,796

 
—

 
12,796

Depreciation and amortization
 
—

 
7,640

 
—

 
7,640

General and administrative
 
751

 
612

 
—

 
1,363

 
 
751

 
21,048

 
—

 
21,799

Operating income (loss)
 
(751
)
 
23,969

 
—

 
23,218

Equity in earnings of subsidiaries
 
22,042

 
—

 
(22,042
)
 
—

Equity in earnings of SLC Pipeline
 
—

 
740

 
—

 
740

Interest income (expense)
 
(6,122
)
 
(2,427
)
 
—

 
(8,549
)
Other
 
—

 
(12
)
 
—

 
(12
)
 
 
15,920

 
(1,699
)
 
(22,042
)
 
(7,821
)
Income before income taxes
 
15,169

 
22,270

 
(22,042
)
 
15,397

State income tax expense
 
—

 
(228
)
 
—

 
(228
)
Net income
 
$
15,169

 
$
22,042

 
$
(22,042
)
 
$
15,169




- 20 -

HOLLY ENERGY PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited) Continued


Condensed Consolidating Statement of Cash Flows
Three Months Ended March 31, 2012
 
Parent
 
Guarantor
Subsidiaries
 
Eliminations
 
Consolidated
 
 
(In thousands)
 
 
 
 
 
 
 
 
 
Cash flows from operating activities
 
$
(106,452
)
 
$
134,675

 
$
—

 
$
28,223

 
 
 
 
 
 
 
 
 
Cash flows from investing activities
 
 
 
 
 
 
 
 
Additions to properties and equipment
 
—

 
(6,327
)
 
—

 
(6,327
)
 
 
 
 
 
 
 
 
 
Cash flows from financing activities
 
 
 
 
 
 
 
 
Net repayments under credit agreement
 
—

 
(45,000
)
 
—

 
(45,000
)
Proceeds from issuance of senior notes
 
294,750

 
—

 
—

 
294,750

Repayments of senior notes
 
(157,761
)
 
—

 
—

 
(157,761
)
Repayment of promissory notes
 
—

 
(72,900
)
 
—

 
(72,900
)
Distributions to HEP unitholders
 
(29,716
)
 
—

 
—

 
(29,716
)
Purchase of units for incentive grants
 
(1,283
)
 
—

 
—

 
(1,283
)
Deferred financing costs
 
—

 
(1,123
)
 
—

 
(1,123
)
Other
 
462

 
(192
)
—

—

 
270

 
 
106,452

 
(119,215
)
 
—

 
(12,763
)
Cash and cash equivalents
 
 
 
 
 
 
 
 
Increase for the period
 
—

 
9,133

 
—

 
9,133

Beginning of period
 
2

 
3,267

 
—

 
3,269

End of period
 
$
2

 
$
12,400

 
$
—

 
$
12,402



Condensed Consolidating Statement of Cash Flows
Three Months Ended March 31, 2011
 
Parent
 
Guarantor
Subsidiaries
 
Eliminations
 
Consolidated
 
 
(In thousands)
 
 
 
 
 
 
 
 
 
Cash flows from operating activities
 
$
22,604

 
$
(7,382
)
 
$
—

 
$
15,222

 
 
 
 
 
 
 
 
 
Cash flows from investing activities
 
 
 
 
 
 
 
 
Additions to properties and equipment
 
—

 
(11,475
)
 
—

 
(11,475
)
 
 
 
 
 
 
 
 
 
Cash flows from financing activities
 
 
 
 
 
 
 
 
Net borrowings under credit agreement
 
—

 
23,000

 
—

 
23,000

Distributions to HEP unitholders
 
(22,205
)
 
—

 
—

 
(22,205
)
Purchase of units for incentive grants
 
(399
)
 
—

 
—

 
(399
)
Deferred financing costs
 
—

 
(3,044
)
 
—

 
(3,044
)
 
 
(22,604
)
 
19,956

 
—

 
(2,648
)
Cash and cash equivalents
 
 
 
 
 
 
 
 
Increase for the period
 
—

 
1,099

 
—

 
1,099

Beginning of period
 
2

 
401

 
—

 
403

End of period
 
$
2

 
$
1,500

 
$
—

 
$
1,502



- 21 -

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 on “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 oil 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. HFC currently owns a 42% interest in us including the 2% general partnership interest.

We also own and operate refined product pipelines and terminals, located primarily in Texas, that service Alon’s (“Alon”) refinery in Big Spring, Texas. Additionally, we own a 25% joint venture interest in the SLC Pipeline (the “SLC Pipeline”), a 95-mile intrastate crude oil pipeline system that serves refineries in the Salt Lake City 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.

Legacy Frontier Pipeline and Tankage Asset Transaction
On November 9, 2011, we acquired from HFC certain tankage, loading rack and crude receiving assets located at HFC’s El Dorado and Cheyenne refineries. We paid non-cash consideration consisting of promissory notes with an aggregate principal amount of $150 million and 3,807,615 of our common units.

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 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 1, based on the Producer Price Index (“PPI”) or Federal Energy Regulatory Commission (“FERC”) index. As of March 31, 2012, these agreements with HFC will result in minimum annualized payments to us of $191.8 million.

If HFC fails to meet its minimum volume commitments under the agreements in any quarter, it will be required to pay us in cash the amount of any shortfall 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 also is subject to annual tariff rate adjustments. Additionally, we have a capacity lease agreement with Alon 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 March 31, 2012, these agreements with Alon will result in minimum annualized payments to us of $30.9 million.

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

Under certain provisions of the Omnibus Agreement (“Omnibus Agreement”) that we have with HFC, we pay HFC an annual administrative fee, currently $2.3 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 pipeline and terminal personnel 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.




- 22 -

RESULTS OF OPERATIONS (Unaudited)

Income, Distributable Cash Flow and Volumes
The following tables present income, distributable cash flow and volume information for the three months ended March 31, 2012 and 2011.
 
 
Three Months Ended March 31,
 
Change from
 
 
2012
 
2011
 
2011
 
 
(In thousands, except per unit data)
Revenues
 
 
 
 
 
 
Pipelines:
 
 
 
 
 
 
Affiliates—refined product pipelines
 
$
12,357

 
$
9,858

 
$
2,499

Affiliates—intermediate pipelines
 
7,045

 
4,633

 
2,412

Affiliates—crude pipelines
 
10,545

 
9,321

 
1,224

 
 
29,947

 
23,812

 
6,135

Third parties—refined product pipelines
 
8,328

 
9,155

 
(827
)
 
 
38,275

 
32,967

 
5,308

Terminals, tanks and loading racks:
 
 
 
 
 
 
Affiliates
 
22,846

 
10,295

 
12,551

Third parties
 
2,394

 
1,755

 
639

 
 
25,240

 
12,050

 
13,190

Total revenues
 
63,515

 
45,017

 
18,498

Operating costs and expenses
 
 
 
 
 
 
Operations
 
16,988

 
12,796

 
4,192

Depreciation and amortization
 
10,264

 
7,640

 
2,624

General and administrative
 
2,039

 
1,363

 
676

 
 
29,291

 
21,799

 
7,492

Operating income
 
34,224

 
23,218

 
11,006

Equity in earnings of SLC Pipeline
 
831

 
740

 
91

Interest expense, including amortization
 
(10,405
)
 
(8,549
)
 
(1,856
)
Loss on early extinguishment of debt
 
(2,596
)
 
—

 
(2,596
)
Other expense
 
—

 
(12
)
 
12

 
 
(12,170
)
 
(7,821
)
 
(4,349
)
Income before income taxes
 
22,054

 
15,397

 
6,657

State income tax
 
(75
)
 
(228
)
 
153

Net income
 
21,979

 
15,169

 
6,810

Less general partner interest in net income, including incentive distributions (1)
 
5,507

 
3,562

 
1,945

Limited partners’ interest in net income
 
$
16,472

 
$
11,607

 
$
4,865

Limited partners’ earnings per unit—basic and diluted (1)
 
$
0.60

 
$
0.53

 
$
0.07

Weighted average limited partners’ units outstanding
 
27,361

 
22,079

 
5,282

EBITDA (2)
 
$
45,319

 
$
31,586

 
$
13,733

Distributable cash flow (3)
 
$
36,555

 
$
20,772

 
$
15,783

Volumes (bpd)
 
 
 
 
 
 
Pipelines:
 
 
 
 
 
 
Affiliates—refined product pipelines
 
97,226

 
77,218

 
20,008

Affiliates—intermediate pipelines
 
123,568

 
68,617

 
54,951

Affiliates—crude pipelines
 
153,662

 
136,257

 
17,405

 
 
374,456

 
282,092

 
92,364

Third parties—refined product pipelines
 
64,287

 
48,528

 
15,759

 
 
438,743

 
330,620

 
108,123

Terminals and loading racks:
 
 
 
 
 

Affiliates
 
262,230

 
157,932

 
104,298

Third parties
 
52,383

 
40,356

 
12,027

 
 
314,613

 
198,288

 
116,325

Total for pipelines and terminal assets (bpd)
 
753,356

 
528,908

 
224,448



- 23 -

(1)
Net income is allocated between limited partners and the general partner interest in accordance with the provisions of the partnership agreement. Net income allocated to the general partner includes incentive distributions declared subsequent to quarter end. Net income attributable to the limited partners is divided by the weighted average limited partner units outstanding in computing the limited partners’ per unit interest in net income.

(2)
EBITDA is calculated as net income plus (i) interest expense, net of interest income, (ii) state income tax and (iii) depreciation and amortization. EBITDA is not a calculation based upon U.S. generally accepted accounting principles (“GAAP”). However, the amounts included in the EBITDA calculation are derived from amounts included in our consolidated financial statements. EBITDA should not be considered 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. 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 also is 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 March 31,
 
 
2012
 
2011
 
 
(In thousands)
 
 
 
 
 
Net income
 
$
21,979

 
$
15,169

Add (subtract):
 
 
 
 
Interest expense
 
8,760

 
8,259

Loss on early extinguishment of debt
 
2,596

 
—

Amortization of discount and deferred debt charges
 
1,645

 
290

State income tax
 
75

 
228

Depreciation and amortization
 
10,264

 
7,640

EBITDA
 
$
45,319

 
$
31,586


(3)
Distributable cash flow is not a calculation based upon GAAP. However, the amounts included in the calculation are derived from amounts separately presented in our consolidated financial statements, with the exception of billed crude revenue settlement and 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.


- 24 -

Set forth below is our calculation of distributable cash flow.
 
 
Three Months Ended March 31,
 
 
2012
 
2011
 
 
(In thousands)
 
 
 
 
 
Net income
 
$
21,979

 
$
15,169

Add (subtract):
 
 
 
 
Depreciation and amortization
 
10,264

 
7,640

Amortization of discount and deferred debt charges
 
1,645

 
290

Loss on early extinguishment of debt
 
2,596

 
—

Billed crude revenue settlement
 
918

 
—

Increase (decrease) in deferred revenue
 
(592
)
 
(1,104
)
Maintenance capital expenditures (4)
 
(307
)
 
(1,229
)
       Other non-cash adjustments
 
52

 
6

Distributable cash flow
 
$
36,555

 
$
20,772


(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 and safety and to address environmental regulations.
 
 
March 31,
2012
 
December 31,
2011
 
 
(In thousands)
Balance Sheet Data
 
 
 
 
Cash and cash equivalents
 
$
12,402

 
$
3,269

Working capital
 
$
815

 
$
12,293

Total assets
 
$
972,838

 
$
966,956

Long-term debt
 
$
597,956

 
$
605,888

Partners’ equity (5)
 
$
321,473

 
$
329,377


(5)
As a master limited partnership, we distribute our available cash, which historically has exceeded our net income 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. Additionally, if the assets contributed and acquired from HFC while under common control of HFC had been acquired from third parties, our acquisition cost in excess of HFC’s basis in the transferred assets of $295.6 million would have been recorded in our financial statements as increases to our properties and equipment and intangible assets instead of decreases to partners’ equity.


Results of Operations—Three Months Ended March 31, 2012 Compared with Three Months Ended March 31, 2011

Summary
Net income for the three months ended March 31, 2012 was $22.0 million, a $6.8 million increase compared to the three months ended March 31, 2011. This increase in earnings is due principally to increased pipeline shipments, earnings attributable to our recent acquisitions and annual tariff increases. These factors were offset partially by a decrease in previously deferred revenue realized, increased operating costs and expenses and a loss incurred on the early extinguishment of certain long-term debt.

Revenues for the three months ended March 31, 2012 include the recognition of $1.7 million of prior shortfalls billed to shippers in 2011. Deficiency payments of $1.1 million associated with certain guaranteed shipping contracts were deferred during the three months ended March 31, 2012. Such deferred revenue will be recognized in earnings either as payment for shipments in excess of guaranteed levels, or when shipping rights expire unused.

Revenues
Total revenues for the three months ended March 31, 2012 were $63.5 million, an $18.5 million increase compared to the three

- 25 -

months ended March 31, 2011. This is due principally to overall increased pipeline shipments, revenues attributable to our November 2011 asset acquisitions and the effect of annual tariff increases, partially offset by a $2.4 million decrease in previously deferred revenue realized.

Overall pipeline volumes were up 33% compared to the three months ended March 31, 2011. During the first quarter of 2011, related-party throughput volumes were below target levels due to production downtime at HFC's Navajo refinery following a plant-wide power outage in January 2011.

Revenues from our refined product pipelines were $20.7 million, an increase of $1.7 million compared to the three months ended March 31, 2011. This includes the effects of a $2.4 million decrease in previously deferred revenue realized. Volumes shipped on our refined product pipelines averaged 161.5 thousand barrels per day ("mbpd") compared to 125.7 mbpd for the same period last year.

Revenues from our intermediate pipelines were $7.0 million, an increase of $2.4 million compared to the three months ended March 31, 2011. This includes $1.2 million in revenues attributable to the Tulsa interconnect pipelines which commenced operations in September 2011, and a $0.5 million increase in previously deferred revenue realized. Volumes shipped on our intermediate pipelines averaged 123.6 mbpd compared to 68.6 mbpd for the same period last year.

Revenues from our crude pipelines were $10.5 million, an increase of $1.2 million compared to the three months ended March 31, 2011. Volumes shipped on our crude pipelines increased to an average of 153.7 mbpd compared to 136.3 mbpd for the same period last year.

Revenues from terminal, tankage and loading rack fees were $25.2 million, an increase of $13.2 million compared to the three months ended March 31, 2011. This increase is due principally to $11.7 million in revenues attributable to our terminal, tankage and loading racks serving HFC's El Dorado and Cheyenne refineries. Refined products terminalled in our facilities increased to an average of 314.6 mbpd compared to 198.3 mbpd for the same period last year.

Operations Expense
Operations expense for the three months ended March 31, 2012 increased by $4.2 million compared to the three months ended March 31, 2011. This increase is due principally to operating costs attributable to our recently acquired assets serving HFC's El Dorado and Cheyenne refineries of $1.4 million and year-over-year increases in first quarter maintenance service and payroll costs.

Depreciation and Amortization
Depreciation and amortization for the three months ended March 31, 2012 increased by $2.6 million compared to the three months ended March 31, 2011. This increase is due principally to depreciation attributable to our recent asset acquisitions from HFC of $1.0 million and capital projects.

General and Administrative
General and administrative costs for the three months ended March 31, 2012 increased by $0.7 million compared to the three months ended March 31, 2011 due to higher professional fees related to our recent transactions.

Equity in Earnings of SLC Pipeline
Our equity in earnings of the SLC Pipeline was $0.8 million for the three months ended March 31, 2012 compared to $0.7 million for the three months ended March 31, 2011.

Interest Expense
Interest expense for the three months ended March 31, 2012 totaled $10.4 million, an increase of $1.9 million compared to the three months ended March 31, 2011. This increase reflects interest on a year-over-year increase in debt levels. Our aggregate effective interest rate was 7.9% for the three months ended March 31, 2012 compared to 6.8% for the same period of 2011.

Loss on Early Extinguishment of Debt
We recognized a charge of $2.6 million upon the early extinguishment of our 6.25% senior notes for the three months ended March 31, 2012. This charge relates to the premium paid to note holders upon their tender of an aggregate principal amount of $157.8 million and related financing costs that were previously deferred.

State Income Tax
We recorded state income taxes of $75,000 and $228,000 for the three months ended March 31, 2012 and 2011, respectively, which are solely attributable to the Texas margin tax.

- 26 -


LIQUIDITY AND CAPITAL RESOURCES

Overview
We have a $375 million senior secured revolving credit facility expiring in February 2016 (the “Credit Agreement”) that is available to fund capital expenditures, investments, acquisitions, distribution payments and working capital and for general partnership purposes. Also it is available to fund letters of credit up to a $50 million sub-limit and to fund distributions to unitholders up to a $30 million sub-limit. In February 2012 we amended our previous credit agreement increasing the size of the credit facility from $275 million to $375 million.

During the three months ended March 31, 2012, we received advances totaling $36.0 million and repaid $81.0 million, resulting in net repayments of $45.0 million under the Credit Agreement. There was an outstanding balance of $155.0 million at March 31, 2012.

Under our registration statement filed with the SEC using a “shelf” registration process, we currently have the ability to raise up to $781.0 million 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, we paid regular quarterly cash distributions of $0.885 on all units in an aggregate amount of $29.7 million. Included in these distributions were $4.9 million of incentive distribution payments to the general partner.

Cash and cash equivalents increased by $9.1 million during the three months ended March 31, 2012. The cash flows provided by operating activities of $28.2 million exceeded the combined cash flows used for investing and financing activities of $6.3 million and $12.8 million, respectively. Working capital decreased by $11.5 million to $0.8 million at March 31, 2012 from $12.3 million at December 31, 2011.

Cash Flows—Operating Activities
Cash flows from operating activities increased by $13.0 million from $15.2 million for the three months ended March 31, 2011 to $28.2 million for the three months ended March 31, 2012. This increase is due principally to $18.5 million in additional cash collections from our customers, partially offset by payments attributable to increased interest and operating expenses.

Our major shippers are obligated to make deficiency payments to us if they do not meet their minimum volume shipping obligations. Under certain agreements with these shippers, they have the right to recapture these amounts if future volumes exceed minimum levels. We billed $1.7 million during the three months ended March 31, 2011 related to shortfalls that subsequently expired without recapture and were recognized as revenue during the three months ended March 31, 2012. Another $1.1 million is included in our accounts receivable at March 31, 2012 related to shortfalls that occurred during the first quarter of 2012.

Cash Flows—Investing Activities
Cash flows used for investing activities decreased by $5.1 million from $11.5 million for the three months ended March 31, 2011 to $6.3 million for the three months ended March 31, 2012. During the three months ended March 31, 2012 and 2011, we invested $6.3 million and $11.5 million in additions to properties and equipment, respectively.

Cash Flows—Financing Activities
Cash flows used for financing activities were $12.8 million for the three months ended March 31, 2012 compared to $2.6 million for the three months ended March 31, 2011, an increase of $10.1 million. During the three months ended March 31, 2012, we received $36.0 million and repaid $81.0 million in advances under the Credit Agreement, received net proceeds of $294.8 million from the issuance of our 6.5% senior notes, and repaid $157.8 million and $72.9 million of our 6.25% senior notes and promissory notes, respectively. Additionally, we paid $29.7 million in regular quarterly cash distributions to our general and limited partners, paid $1.1 million in financing costs to amend our previous credit agreement and paid $1.3 million for the purchase of common units for recipients of our incentive grants. During the three months ended March 31, 2011, we received $30.0 million and repaid $7.0 million in advances under the Credit Agreement. Additionally, we paid $22.2 million in regular quarterly cash distributions to our general and limited partners, incurred $3.0 million in financing costs upon the issuance of the 8.25% Senior Notes, and paid $0.4 million for the purchase of common units for recipients of our incentive grants.

- 27 -

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 consist of maintenance capital expenditures and expansion capital expenditures. 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 Holly Logistic Services, L.L.C. (“HLS”) board 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, special 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 2012 capital budget is comprised of $8.9 million for maintenance capital expenditures and $25.8 million for expansion capital expenditures.

We recently have made certain modifications to our crude oil gathering and trunk line system that effectively have increased our ability to gather and transport an additional 10,000 bpd of Delaware Basin crude oil in response to increased drilling activity in southeast New Mexico. Furthermore, we have developed a project to replace a 5-mile section of this pipeline system that will allow for an additional 15,000 bpd of capacity that will be executed as needed if Delaware Basin crude volumes continue to increase. This project is estimated to cost approximately $2.0 million. We have a second project that consists of the reactivation and conversion to crude oil service of a 70-mile, 8-inch petroleum products pipeline owned by us. Once in service, this pipeline will initially be capable of transporting up to 35,000 bpd of crude oil from southeast New Mexico to third-party common carrier pipelines in west Texas for further transport to major crude oil markets. The scope of this project is being finalized. Subject to receipt of acceptable shipper support and board approval, this project could be operational in early 2013.

We are in discussions with HFC regarding our option to purchase its 75% equity interest in the UNEV Pipeline, a joint venture pipeline that is capable of transporting refined petroleum products from Salt Lake City, Utah to Las Vegas, Nevada. The initial capacity of this pipeline is 62,000 bpd, with the capacity for further expansion to 120,000 bpd. The total construction cost of this pipeline, including terminals, ethanol blending and storage facilities, was approximately $410.0 million. HFC's share of the cost is $308.0 million. The pipeline was mechanically complete in November 2011, and initial start-up activities commenced in December 2011. We are not obligated to purchase the UNEV Pipeline nor are we subject to any fees or penalties if HLS' board of directors decides not to proceed with this opportunity.

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

Credit Agreement
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 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 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 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 agreement, the lenders will be able to accelerate the maturity of the debt and exercise other rights and remedies.

Senior Notes
In March 2012, we issued $300 million in aggregate principal amount outstanding of 6.5% senior notes maturing March 1, 2020. The $294.8 million in net proceeds from the issuance were used to fund $157.8 million aggregate principal amount of 6.25% senior notes tendered pursuant to a cash tender offer and consent solicitation announced in February 2012, to repay $72.9 million

- 28 -

in Promissory Notes due to HFC as discussed below, related fees, expenses and accrued interest in connection with these transactions and to repay borrowings under the Credit Agreement.

In April 2012, we called for redemption $27.2 million aggregate principal amount of 6.25% senior notes that remained outstanding following the cash tender offer and consent solicitation.

In March 2010, we issued $150 million in aggregate principal amount outstanding of 8.25% senior notes maturing March 15, 2018. A portion of the $147.5 million in net proceeds from the issuance was used to fund our $93.0 million purchase of the Tulsa and Lovington storage assets from HFC on March 31, 2010. Additionally, we used a portion to repay $42.0 million in outstanding Credit Agreement borrowings, with the remaining proceeds available for general partnership purposes, including working capital and capital expenditures.

Our 6.5% senior notes and 8.25% senior notes (collectively, the “Senior Notes”) are unsecured and impose certain restrictive covenants which we are subject to and currently in compliance with, 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 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 under the Senior Notes.

Indebtedness under the Senior Notes is recourse to HEP Logistics, and 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.

Promissory Notes
In November 2011, we issued senior unsecured promissory notes to HFC (the “Promissory Notes”) having an aggregate principal amount of $150.0 million to finance a portion of our November 9, 2011 acquisition of certain tankage, loading rack and crude receiving assets located at HFC's El Dorado and Cheyenne refineries. In December 2011, we repaid $77.1 million of outstanding principal using proceeds received in our December 2011 common unit offering and existing cash. We repaid the remaining $72.9 million balance in March 2012.

Long-term Debt
The carrying amounts of our long-term debt are as follows:
 
 
March 31,
2012
 
December 31,
2011
 
 
(In thousands)
Credit Agreement
 
$
155,000

 
$
200,000

 
 
 
 
 
6.5% Senior Notes
 
 
 
 
Principal
 
300,000

 
—

Unamortized discount
 
(5,214
)
 
—

 
 
294,786

 
—

6.25% Senior Notes
 
 
 
 
Principal
 
27,254

 
185,000

Unamortized net discount
 
(15
)
 
(105
)
 
 
27,239

 
184,895

8.25% Senior Notes
 
 
 
 
Principal
 
150,000

 
150,000

Unamortized discount
 
(1,830
)
 
(1,907
)
 
 
148,170

 
148,093

 
 
 
 
 
Promissory Notes
 
—

 
72,900

 
 
 
 
 
Total debt
 
625,195

 
605,888

Less current portion of long-term debt
 
27,239

 
—

 
 
 
 
 
Total long-term debt, net of current portion
 
$
597,956

 
$
605,888


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

Contractual Obligations
In February 2012, we amended our previous credit agreement increasing the size of the credit facility from $275 million to $375 million. The Credit Agreement expires in February 2016. During the three months ended March 31, 2012, we repaid net advances of $45.0 million resulting in $155.0 million of outstanding borrowings under the Credit Agreement at March 31, 2012.

In March 2012, we issued $300 million in aggregate principle amount of 6.5% senior notes maturing March 2020.

There were no other 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 three months ended March 31, 2012 and 2011. Historically, the PPI has increased an average of 3.6% annually over the past 5 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 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 in that the operations of our competitors are similarly affected. We believe that 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 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.

Under the Omnibus Agreement and certain transportation agreements with HFC, HFC has agreed to indemnify us, subject to certain limitations, for environmental noncompliance and remediation liabilities associated with assets transferred to us from HFC and occurring or existing prior to the date of such transfers. The Omnibus Agreement provides environmental indemnification with respect to certain transferred assets of up to $15 million through 2021, plus additional indemnification of $2.5 million through 2015 for certain of these assets and up to $7.5 million through 2023 for certain other assets. HFC’s indemnification obligations under the Omnibus Agreement do not apply to (i) the Tulsa west loading racks acquired in August 2009, (ii) the 16-inch intermediate pipeline acquired in June 2009, (iii) the Roadrunner Pipeline, (iv) the Beeson Pipeline, (v) the logistics and storage assets acquired from Sinclair in December 2009, or (vi) the Tulsa east storage tanks and loading racks acquired in March 2010. For the Tulsa loading racks acquired from HFC in August 2009 and the Tulsa logistics and storage assets acquired from Sinclair in December 2009, HFC agreed to indemnify us for environmental liabilities arising from our pre-ownership operations of these assets. Additionally, HFC agreed to indemnify us for any liabilities arising from its operation of our loading racks located at HFC's Tulsa refinery west facility.

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 through 2015, subject to a $100,000 deductible and a $20 million maximum liability cap.

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 March 31, 2012, we have an accrual of $1.1 million that relates to environmental clean-up

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projects for which we have assumed liability. 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, 2011. 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 2012. 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

Presentation of Comprehensive Income
Effective January 1, 2012,  we adopted the accounting standard update that requires the presentation of net income and other comprehensive income in one continuous statement or in two separate, but consecutive, statements and eliminated the option to present the components of other comprehensive income in the statement of partners' equity.

Intangibles-Goodwill and Other: Testing Goodwill for Impairment
Effective January 1, 2012, we adopted the accounting standard update that allows entities an option to first assess qualitative factors to determine whether it is necessary to perform the two-step quantitative goodwill impairment test. Under this option, we  no longer are required to calculate the fair value of a reporting unit unless we determine, based on that qualitative assessment, that it is more likely than not that the reporting unit's fair value is less than its carrying amount. The adoption of this accounting standard did not have an impact on our financial condition, results of operations and cash flows.


RISK MANAGEMENT

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

As of March 31, 2012, we have an interest rate swap, designated as a cash flow hedge, that hedges our exposure to the cash flow risk caused by the effects of LIBOR changes on a $155.0 million Credit Agreement advance. This 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 currently 2.25%, which equaled an effective interest rate of 3.24% as of March 31, 2012. This swap contract matures in February 2016.

We review publicly available information on our counterparty in order to review and monitor its financial stability and assess its ongoing ability to honor its commitments under the interest rate swap contract. This counterparty is a large financial institution. Furthermore, we have not experienced, nor do we expect to experience, any difficulty in the counterparty honoring its respective commitment.

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

At March 31, 2012, we had an outstanding principal balance on our 6.5% Senior Notes and 8.25% Senior Notes of $300 million, and $150 million, respectively. A change in interest rates would generally affect the fair value of the Senior Notes, but not our earnings or cash flows. At March 31, 2012, the fair values of our 6.5% Senior Notes and 8.25% Senior Notes were $305.3 million and $161.3 million, respectively. We estimate a hypothetical 10% change in the yield-to-maturity applicable to the 6.5% Senior Notes and 8.25% Senior Notes at March 31, 2012 would result in a change of approximately $11.7 million and $5.1 million, respectively, 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 March 31,

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2012, borrowings outstanding under the Credit Agreement were $155.0 million. By means of our cash flow hedge, we have effectively converted the variable rate on $155.0 million of outstanding borrowings to a fixed rate of 3.24%.

At March 31, 2012, our cash and cash equivalents included highly liquid investments with a maturity of three months or less at the time of purchase. Due to the short-term nature of our cash and cash equivalents, a hypothetical 10% increase in interest rates would not have a material effect on the fair market value of our portfolio. Since we have the ability to liquidate this portfolio, we do not expect our operating results or cash flows to be materially affected by the effect of a sudden change in market interest rates on our investment portfolio.

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.

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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 cash and cash equivalents and 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, 2011. 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 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 March 31, 2012.

(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, none of which we believe will 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, 2011. In addition to the other information set forth in this quarterly report, you should carefully consider the factors discussed in our 2011 Form 10-K, which could materially affect our business, financial condition or future results. The risks described in this quarterly report and in our 2011 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 also may materially adversely affect our business, financial condition or future results.


Item 5(a). Other Information.
(a) Mortgages. Effective January 31, 2012, in connection with our acquisition from HFC of certain tankage, loading rack and crude receiving assets located at HFC's El Dorado and Cheyenne refineries in November 2011, our wholly-owned subsidiaries Cheyenne Logistics LLC and El Dorado Logistics LLC each executed a mortgage for the benefit of HFC with respect to such assets located at the Cheyenne refinery and the El Dorado refinery, respectively. Each mortgage grants HFC a second priority lien on the applicable assets and provides HFC with certain rights to take possession of and/or operate such assets upon a default of the mortgage, in each case consistent with the mortgages that we have executed in favor of HFC in connection with our previous acquisitions from HFC. The descriptions of the mortgages herein are qualified by reference to the copy of the Cheyenne mortgage, filed as Exhibit 10.61 to our Annual Report on Form 10-K for our fiscal year ended December 31, 2011, and the El Dorado mortgage, filed as Exhibit 10.2 to this report, each of which is incorporated by reference into this report in its entirety.

Item 6.
Exhibits

The Exhibit Index on page 38 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: May 1, 2012
 
/s/    Bruce R. Shaw        
 
 
Bruce R. Shaw
 
 
Senior Vice President and
Chief Financial Officer
(Principal Financial Officer)
 
 
 
 
 
/s/     Scott C. Surplus        
 
 
Scott C. Surplus
 
 
Vice President and Controller
(Principal Accounting Officer)
 


- 35 -

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 filed April 15, 2008, File No. 1-32225).
 
 
  3.5
  
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).
 
 
  3.6
  
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).
 
 
  3.7
  
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).
 
 
  3.8
  
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).
 
 
  3.9
  
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).
 
 
 
  4.1
 
Indenture, dated March 12, 2012, among Holly Energy Partners, L.P., Holly Energy Finance Corp., the Subsidiary Guarantors named therein and U.S. Bank National Association, as Trustee (incorporated by reference to Exhibit 4.1 of Registrant's Current Report on Form 8-K dated March 12, 2012, File No. 1-32225).
 
 
 
  4.2
 
Tenth Supplemental Indenture, dated as of March 12, 2012, by and among Holly Energy Partners, L.P., Holly Energy Finance Corp., the Subsidiary Guarantors named therein and U.S. Bank National Association, as Trustee, to the Indenture, dated as of February 28, 2005, as amended and supplemented, by and among Holly Energy Partners, L.P., Holly Energy Finance Corp., the Subsidiary Guarantors named therein and U.S. Bank National Association, as Trustee (incorporated by reference to Exhibit 4.2 of Registrant's Current Report on Form 8-K dated March 12, 2012, File No. 1-32225).
 
 
 
10.1
  
Mortgage and Deed of Trust, dated January 31, 2012, by Cheyenne Logistics LLC for the benefit of HollyFrontier Corporation (incorporated by reference to Exhibit 10.61 of Registrant's Annual Report on Form 10-K for its fiscal year ended December 31, 2011, File No. 1-32225).
 
 
 
10.2+
  
Mortgage and Deed of Trust, dated January 31, 2012, by El Dorado Logistics LLC for the benefit of HollyFrontier Corporation.
 
 
 

- 36 -

10.3
  
Agreement and Amendment No.1 to Second Amended and Restated Credit Agreement dated February 3, 2012, among Holly Energy Partners - Operating, L.P., certain of its subsidiaries acting as guarantors, Wells Fargo Bank, N.A., as administrative agent, an issuing bank and a lender, and certain other lenders party thereto (incorporated by reference to Exhibit 10.1 of Registrant's Current Report on Form 8-K dated February 9, 2012, File No. 1-32225).
 
 
 
10.4
 
Purchase Agreement, dated February 28, 2012, among Holly Energy Partners, L.P., Holly Energy Finance Corp., and each of the guarantors party thereto and Citigroup Global Markets Inc., UBS Securities LLC, and Wells Fargo Securities, LLC, as representatives of the initial purchasers named therein (incorporated by reference to Exhibit 10.1 of Registrant's Current Report on Form 8-K dated March 5, 2012, File No. 1-32225).
 
 
 
12.1+
 
Computation of Ratio of Earnings to Fixed Charges.
 
 
 
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 March 31, 2012, 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.
 **
Furnished electronically herewith.

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