Form 10-Q
Table of Contents

 
 
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
     
þ   QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended March 31, 2011
OR
     
o   TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES 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   (I.R.S. Employer
incorporation or organization)   Identification No.)
100 Crescent Court, Suite 1600
Dallas, Texas 75201-6915
(Address of principal executive offices)
(214) 871-3555
(Registrant’s telephone number, including area code)
None
(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 þ No o
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 o No o
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 o   Accelerated filer þ   Non-accelerated filer o   Smaller reporting company o
Indicate by check mark whether the registrant is a shell company (as defined by Rule 12b-2 of the Exchange Act).
Yes o No þ
The number of the registrant’s outstanding common units at April 22, 2011 was 22,078,509.
 
 

 

 


 

HOLLY ENERGY PARTNERS, L.P.
INDEX
         
    3  
 
       
    3  
 
       
    4  
 
       
    4  
 
       
    5  
 
       
    6  
 
       
    7  
 
       
    8  
 
       
    21  
 
       
    34  
 
       
    34  
 
       
    35  
 
       
    35  
 
       
    35  
 
       
    36  
 
       
    37  
 
       
 Exhibit 12.1
 Exhibit 31.1
 Exhibit 31.2
 Exhibit 32.1
 Exhibit 32.2

 

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PART I. FINANCIAL INFORMATION
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 in our terminals;
   
the economic viability of Holly 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 risk factors and other cautionary statements set forth in our Annual Report on Form 10-K for the year ended December 31, 2010 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.

 

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Item 1.  
Financial Statements
Holly Energy Partners, L.P.
Consolidated Balance Sheets
                 
    March 31, 2011     December 31,  
    (Unaudited)     2010  
    (In thousands, except unit data)  
ASSETS
               
Current assets:
               
Cash and cash equivalents
  $ 1,502     $ 403  
Accounts receivable:
               
Trade
    3,102       3,544  
Affiliates
    20,373       18,964  
 
           
 
    23,475       22,508  
 
               
Prepaid and other current assets
    546       775  
 
           
Total current assets
    25,523       23,686  
 
               
Properties and equipment, net
    440,523       434,950  
Transportation agreements, net
    106,753       108,489  
Goodwill
    49,109       49,109  
Investment in SLC Pipeline
    25,802       25,437  
Other assets
    4,440       1,602  
 
           
 
               
Total assets
  $ 652,150     $ 643,273  
 
           
 
               
LIABILITIES AND PARTNERS’ EQUITY
               
Current liabilities:
               
Accounts payable:
               
Trade
  $ 5,991     $ 6,347  
Affiliates
    4,334       3,891  
 
           
 
    10,325       10,238  
 
               
Accrued interest
    1,541       7,517  
Deferred revenue
    9,333       10,437  
Accrued property taxes
    1,738       1,990  
Other current liabilities
    1,079       1,262  
 
           
Total current liabilities
    24,016       31,444  
 
               
Long-term debt
    514,733       491,648  
Other long-term liabilities
    9,511       10,809  
 
               
Partners’ equity:
               
Common unitholders (22,078,509 units issued and outstanding at March 31, 2011 and December 31, 2010)
    265,087       271,649  
General partner interest (2% interest)
    (152,454 )     (152,251 )
Accumulated other comprehensive loss
    (8,743 )     (10,026 )
 
           
 
               
Total partners’ equity
    103,890       109,372  
 
           
 
               
Total liabilities and partners’ equity
  $ 652,150     $ 643,273  
 
           
See accompanying notes.

 

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Holly Energy Partners, L.P.
Consolidated Statements of Income
(Unaudited)
                 
    Three Months Ended  
    March 31,  
    2011     2010  
    (In thousands, except per unit data)  
Revenues:
               
Affiliates
  $ 34,107     $ 33,597  
Third parties
    10,910       7,099  
 
           
 
    45,017       40,696  
 
           
 
               
Operating costs and expenses:
               
Operations
    12,796       13,060  
Depreciation and amortization
    7,640       7,210  
General and administrative
    1,363       2,563  
 
           
 
    21,799       22,833  
 
           
 
               
Operating income
    23,218       17,863  
 
               
Other income (expense):
               
Equity in earnings of SLC Pipeline
    740       481  
Interest income
          3  
Interest expense
    (8,549 )     (7,544 )
Other expense
    (12 )     (7 )
 
           
 
    (7,821 )     (7,067 )
 
           
 
               
Income before income taxes
    15,397       10,796  
 
               
State income tax
    (228 )     (94 )
 
           
 
               
Net income
    15,169       10,702  
 
               
Less general partner interest in net income, including incentive distributions
    3,562       2,646  
 
           
 
               
Limited partners’ interest in net income
  $ 11,607     $ 8,056  
 
           
 
               
Limited partners’ per unit interest in earnings — basic and diluted:
  $ 0.53     $ 0.36  
 
           
 
               
Weighted average limited partners’ units outstanding
    22,079       22,079  
 
           
See accompanying notes.

 

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Holly Energy Partners, L.P.
Consolidated Statements of Cash Flows
(Unaudited)
                 
    Three Months Ended  
    March 31,  
    2011     2010  
    (In thousands)  
Cash flows from operating activities
               
Net income
  $ 15,169     $ 10,702  
Adjustments to reconcile net income to net cash provided by operating activities:
               
Depreciation and amortization
    7,640       7,210  
Equity in earnings of SLC Pipeline, net of distributions
    (365 )     (481 )
Change in fair value — interest rate swaps
          1,464  
Amortization of restricted and performance units
    670       966  
(Increase) decrease in current assets:
               
Accounts receivable — trade
    442       392  
Accounts receivable — affiliates
    (1,409 )     (2,081 )
Prepaid and other current assets
    229       225  
Current assets of discontinued operations
          2,195  
Increase (decrease) in current liabilities:
               
Accounts payable — trade
    (356 )     (499 )
Accounts payable — affiliates
    443       504  
Accrued interest
    (5,976 )     (1,157 )
Deferred revenue
    (1,104 )     1,108  
Accrued property taxes
    (252 )     (214 )
Other current liabilities
    (183 )     (109 )
Other, net
    274       (1,502 )
 
           
Net cash provided by operating activities
    15,222       18,723  
 
               
Cash flows from investing activities
               
Additions to properties and equipment
    (11,475 )     (1,911 )
Acquisition of assets from Holly Corporation
          (37,234 )
 
           
Net cash used for investing activities
    (11,475 )     (39,145 )
 
               
Cash flows from financing activities
               
Borrowings under credit agreement
    30,000       33,000  
Repayments of credit agreement borrowings
    (7,000 )     (68,000 )
Proceeds from issuance of senior notes
          147,540  
Distributions to HEP unitholders
    (22,205 )     (20,506 )
Purchase price in excess of transferred basis in assets acquired from Holly Corporation
          (55,766 )
Purchase of units for restricted grants
    (399 )     (1,745 )
Deferred financing costs
    (3,044 )      
 
           
Net cash provided by (used for) financing activities
    (2,648 )     34,523  
 
               
Cash and cash equivalents
               
Increase for the period
    1,099       14,101  
Beginning of period
    403       2,508  
 
           
 
               
End of period
  $ 1,502     $ 16,609  
 
           
See accompanying notes.

 

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Holly Energy Partners, L.P.
Consolidated Statement of Partners’ Equity
(Unaudited)
                                 
                    Accumulated        
            General     Other        
    Common     Partner     Comprehensive        
    Units     Interest     Loss     Total  
 
                               
Balance December 31, 2010
  $ 271,649     $ (152,251 )   $ (10,026 )   $ 109,372  
 
                               
Distributions to HEP unitholders
    (18,648 )     (3,557 )           (22,205 )
Purchase of units for restricted grants
    (399 )                 (399 )
Amortization of restricted and performance units
    670                   670  
Comprehensive income:
                               
Net income
    11,815       3,354             15,169  
Other comprehensive income
                1,283       1,283  
 
                       
Comprehensive income
    11,815       3,354       1,283       16,452  
 
                       
 
                               
Balance March 31, 2011
  $ 265,087     $ (152,454 )   $ (8,743 )   $ 103,890  
 
                       
See accompanying notes.

 

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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 34% owned (including the 2% general partner interest) by Holly Corporation (“Holly”) and its subsidiaries. We commenced operations on July 13, 2004 upon the completion of our initial public offering. In these consolidated financial statements, the words “we,” “our,” “ours” and “us” refer to HEP unless the context otherwise indicates.
We operate in one business 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 Holly’s refining and marketing operations in west Texas, New Mexico, Utah, Oklahoma, Idaho and Arizona. We also own and operate refined product pipelines and terminals, located primarily in Texas, that service 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 refined products and other hydrocarbons and storing 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, 2010. 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, 2011.
On the Consolidated Balance Sheet for the year ended December 31, 2010, we have reclassified $10.3 in partner’s equity from the general partner interest to our common unitholders and have revised the corresponding equity balances at December 31, 2010 in the Consolidated Statement of Partners’ Equity. This amount represents general partner incentive distributions paid in 2010 that were incorrectly classified as common unit distributions.
Note 2: Acquisitions
2010 Acquisitions
Tulsa East / Lovington Storage Asset Transaction
On March 31, 2010, we acquired from Holly certain storage assets for $88.6 million consisting of hydrocarbon storage tanks having approximately 2 million barrels of storage capacity, a rail loading rack and a truck unloading rack located at Holly’s Tulsa refinery east facility.
Also, as part of this same transaction, we acquired Holly’s asphalt loading rack facility located at its Navajo refinery facility in Lovington, New Mexico for $4.4 million.

 

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We are a consolidated variable interest entity of Holly. In accounting for these acquisitions from Holly, we recorded total property and equipment at Holly’s cost basis of $37.2 million and the purchase price in excess of Holly’s basis in the assets of $55.8 million as a decrease to our partners’ equity.
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.
Our debt consists of borrowings outstanding under our $275 million revolving credit agreement (the “Credit Agreement”), our 6.25% senior notes due 2015 (the “6.25% Senior Notes”) and our 8.25% senior notes due 2018 (the “8.25% Senior Notes”). The $182 million carrying amount of borrowings outstanding under the Credit Agreement approximates fair value as interest rates are reset frequently using current rates. The estimated fair values of our 6.25% Senior Notes and 8.25% Senior Notes were $185 million and $160.5 million, respectively, at March 31, 2011. These fair value estimates are based on market quotes provided from a third-party bank. See Note 7 for additional information on these instruments.
Fair Value Measurements
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.
We have an interest rate swap that is measured at fair value on a recurring basis using Level 2 inputs that as of March 31, 2011 represented a liability having a fair value of $8.7 million. With respect to this instrument, fair value is based on the net present value of expected future cash flows related to both variable and fixed rate legs of our interest rate swap agreement. Our 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 our interest rate swap.
Note 4: Properties and Equipment
                 
    March 31,     December 31,  
    2011     2010  
    (In thousands)  
 
               
Pipelines and terminals
  $ 509,064     $ 507,260  
Land and right of way
    25,271       25,264  
Other
    15,018       14,591  
Construction in progress
    25,799       16,601  
 
           
 
    575,152       563,716  
Less accumulated depreciation
    134,629       128,766  
 
           
 
  $ 440,523     $ 434,950  
 
           
We capitalized $0.2 million and $0.1 million in interest related to major construction projects during the three months ended March 31, 2011 and 2010, respectively.

 

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Note 5: Transportation Agreements
Our transportation agreements consist of the following:
   
The Alon pipelines and terminals agreement (the “Alon PTA”) represents a portion of the total purchase price of the Alon assets acquired in 2005 that was allocated based on an estimated fair value derived under an income approach. This asset is being amortized over 30 years ending 2035, the 15-year initial term of the Alon PTA plus the expected 15-year extension period.
   
The Holly crude pipelines and tankage agreement (the “Holly CPTA”) represents a portion of the total purchase price of certain crude pipelines and tankage assets acquired from Holly in 2008 (at which time we were not a consolidated variable interest entity of Holly) that was allocated using a fair value based on the agreement’s expected contribution to our future earnings under an income approach. This asset is being amortized over 15 years ending 2023, the 15-year term of the Holly CPTA.
The carrying amounts of our transportation agreements are as follows:
                 
    March 31,     December 31,  
    2011     2010  
    (In thousands)  
 
               
Alon transportation agreement
  $ 59,933     $ 59,933  
Holly crude pipelines and tankage agreement
    74,231       74,231  
 
           
 
    134,164       134,164  
Less accumulated amortization
    27,411       25,675  
 
           
 
  $ 106,753     $ 108,489  
 
           
We have additional transportation agreements with Holly that relate to assets contributed to us or acquired from Holly consisting of pipeline, terminal and tankage assets. These transactions occurred while we were a consolidated variable interest entity of Holly, therefore, our basis in these agreements does not reflect a step-up in basis to fair value.
In addition, we have an agreement to provide transportation and storage services to Holly via our Tulsa logistics and storage assets acquired from Sinclair. Since this agreement is with Holly and not between Sinclair and us, there is no purchase price allocation attributable to this agreement.
Note 6: Employees, Retirement and Incentive Plans
Employees who provide direct services to us are employed by Holly Logistic Services, L.L.C., a Holly 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 Holly. These employees participate in the retirement and benefit plans of Holly. Our share of retirement and benefit plan costs was $0.7 million for the three months ended March 31, 2011 and 2010.
We have adopted 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.
As of March 31, 2011, we have two types of equity-based compensation, which are described below. The compensation cost charged against income for these plans was $0.7 million and $1 million for the three months ended March 31, 2011 and 2010, respectively. We currently purchase units in the open market instead of issuing new units for settlement of restricted unit grants. At March 31, 2011, 350,000 units were authorized to be granted under the equity-based compensation plans, of which 63,027 had not yet been granted.

 

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Restricted Units
Under our Long-Term Incentive Plan, we grant restricted units to selected employees and directors who perform services for us, with vesting generally over a period of one to five 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, 2011 is presented below:
                                 
                    Weighted-        
            Weighted-     Average     Aggregate  
            Average     Remaining     Intrinsic  
            Grant-Date     Contractual     Value  
Restricted Units   Grants     Fair Value     Term     ($000)  
 
                               
Outstanding at January 1, 2011 (nonvested)
    47,295     $ 37.47                  
Granted
    20,924       59.65                  
Vesting and transfer of full ownership to recipients
    (24,055 )     41.48                  
Forfeited
    (7,802 )     43.71                  
 
                             
Outstanding at March 31, 2011 (nonvested)
    36,362     $ 46.24     1.2 years   $ 2,109  
 
                       
The fair value of restricted units that were vested and transferred to recipients during the three months ended March 31, 2011 and 2010 were $1 million and $1.3 million, respectively. As of March 31, 2011, there was $1.1 million of total unrecognized compensation costs related to nonvested restricted unit grants. That cost is expected to be recognized over a weighted-average period of 1.2 years.
During the three months ended March 31, 2011, we paid $0.4 million for the purchase of our common units in the open market for the recipients of our restricted unit grants.
Performance Units
Under our Long-Term Incentive Plan, we grant performance units to selected executives who perform services for us. Performance units granted in 2011 and 2010 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. Performance units granted in 2009 are payable based upon the growth in distributions on our common units during the requisite period, and vest over a period of three years. As of March 31, 2011, estimated share payouts for outstanding nonvested performance unit awards ranged from 110% to 120%.
We granted 12,113 performance units to certain officers in March 2011. These units will vest over a three-year performance period ending December 31, 2013 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. The fair value of these performance units is based on the grant date closing unit price of $59.65 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, 2011 is presented below:
         
    Payable  
Performance Units   In Units  
 
       
Outstanding at January 1, 2011 (nonvested)
    59,415  
Granted
    12,113  
Vesting and transfer of common units to recipients
    (14,337 )
Forfeited
     
 
     
Outstanding at March 31, 2011 (nonvested)
    57,191  
 
     

 

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The fair value of performance units vested and transferred to recipients during the three months ended March 31, 2011 and 2010 was $0.6 million and $0.5 million, respectively. Based on the weighted average fair value at March 31, 2011 of $36.72, there was $1.4 million of total unrecognized compensation cost related to nonvested performance units. That cost is expected to be recognized over a weighted-average period of 1.5 years.
Note 7: Debt
Credit Agreement
We have a $275 million Credit Agreement that is available to fund capital expenditures, investments, acquisitions, distribution payments and working capital and for general partnership purposes. It is also available to fund letters of credit up to a $50 million sub-limit and to fund distributions to unitholders up to a $30 million sub-limit. In February 2011, we amended our previous credit agreement (expiring in August 2011), slightly, reducing the size of the credit facility from $300 million to $275 million. The size was reduced based on management’s review of past and forecasted utilization of the facility. The Credit Agreement expires in February 2016; however, in the event that the 6.25% Senior Notes are not repurchased, refinanced, extended or repaid prior to September 1, 2014, the Credit Agreement shall expire on that date.
During the quarter ended March 31, 2011, we received advances totaling $30 million and repaid $7 million, resulting in net borrowings of $23 million under the Credit Agreement and an outstanding balance of $182 million at March 31, 2011. As of March 31, 2011, we had no working capital borrowings.
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., our general partner, and guaranteed by our material, wholly-owned subsidiaries. Any recourse to HEP Logistics Holdings, L.P. 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.
Indebtedness under the Credit Agreement bears interest, at our option, at either (a) the reference rate as announced by the administrative agent plus an applicable margin (ranging from 1.00% to 2.00%) or (b) at a rate equal to LIBOR plus an applicable margin (ranging from 2.00% to 3.00%). In each case, the applicable margin is based upon the ratio of our funded debt (as defined in the Credit Agreement) to EBITDA (earnings before interest, taxes, depreciation and amortization, as defined in the Credit Agreement). We incur a commitment fee on the unused portion of the Credit Agreement at an annual rate ranging from 0.375% to 0.50% based upon the ratio of our funded debt to EBITDA for the four most recently completed fiscal quarters.
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 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 received was used to fund our $93 million purchase of the Tulsa and Lovington storage assets from Holly on March 31, 2010. Additionally, we used a portion to repay $42 million in outstanding Credit Agreement borrowings, with the remaining proceeds available for general partnership purposes, including working capital and capital expenditures.

 

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Our 6.25% Senior Notes having an aggregate principal amount outstanding of $185 million mature March 1, 2015 and are registered with the SEC. The 6.25% Senior Notes and 8.25% Senior Notes (collectively, the “Senior Notes”) are unsecured and have 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 Holdings, L.P., our general partner, and guaranteed by our wholly-owned subsidiaries. However, any recourse to HEP Logistics Holdings, L.P. would be limited to the extent of its assets, which other than its investment in us, are not significant.
The carrying amounts of our debt are as follows:
                 
    March 31,     December 31,  
    2011     2010  
    (In thousands)  
Credit Agreement
  $ 182,000     $ 159,000  
 
               
6.25% Senior Notes
               
Principal
    185,000       185,000  
Unamortized discount
    (1,489 )     (1,584 )
Unamortized premium — dedesignated fair value hedge
    1,357       1,444  
 
           
 
    184,868       184,860  
 
           
 
               
8.25% Senior Notes
               
Principal
    150,000       150,000  
Unamortized discount
    (2,135 )     (2,212 )
 
           
 
    147,865       147,788  
 
           
 
               
Total long-term debt
  $ 514,733     $ 491,648  
 
           
Interest Rate Risk Management
We use interest rate swaps (derivative instruments) to manage our exposure to interest rate risk.
As of March 31, 2011, 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 million Credit Agreement advance. This interest rate swap effectively converts $155 million of LIBOR based debt to fixed rate debt having an interest rate of 3.74% plus an applicable margin, currently 2.50%, which equals an effective interest rate of 6.24% as of March 31, 2011. This swap contract matures in February 2013.
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 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 million of our variable rate debt. Any ineffectiveness is reclassified from accumulated other comprehensive loss to interest expense. To date, we have had no ineffectiveness on our cash flow hedge.

 

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Additional information on our interest rate swap is as follows:
                         
    Balance Sheet           Location of Offsetting   Offsetting  
Derivative Instrument   Location   Fair Value     Balance   Amount  
    (In thousands)  
March 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
  $ 8,743    
Accumulated other
comprehensive loss
  $ 8,743  
 
                   
 
                       
December 31, 2010
                       
 
                       
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
  $ 10,026    
Accumulated other
comprehensive loss
  $ 10,026  
 
                   
Interest Expense and Other Debt Information
Interest expense consists of the following components:
                 
    March 31,     March 31,  
    2011     2010  
    (In thousands)  
Interest on outstanding debt:
               
Credit Agreement, net of interest on interest rate swap
  $ 2,365     $ 2,472  
6.25% Senior Notes, net of interest on interest rate swaps
    2,891       2,732  
8.25% Senior Notes
    3,094       722  
Net fair value adjustments to interest rate swaps (1)
          1,464  
Net amortization of discount and deferred debt issuance costs
    290       194  
Commitment fees
    113       77  
 
           
Total interest incurred
    8,753       7,661  
 
               
Less capitalized interest
    204       117  
 
           
 
               
Net interest expense
  $ 8,549     $ 7,544  
 
           
 
               
Cash paid for interest (2)
  $ 14,439     $ 10,587  
 
           
(1)  
Represents fair value adjustments to interest rate swap agreements settled during the first quarter of 2010.
 
(2)  
Net of cash received under previous interest rate swap agreements of $1.9 million for the three months ended March 31, 2010.
Note 8: Significant Customers
All revenues are domestic revenues, of which 96% are currently generated from our two largest customers: Holly 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,  
    2011     2010  
Holly
    76 %     83 %
Alon
    20 %     13 %

 

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Note 9: Related Party Transactions
Holly Agreements
We serve Holly’s refineries in New Mexico, Utah and Oklahoma under the following long-term pipeline and terminal, tankage and throughput agreements:
   
Holly PTA (pipelines and terminals throughput agreement expiring in 2019 that relates to assets contributed to us by Holly upon our initial public offering in 2004);
   
Holly IPA (intermediate pipelines throughput agreement expiring in 2024 that relates to assets acquired from Holly in 2005 and 2009);
   
Holly CPTA (crude pipelines and tankage throughput agreement expiring in 2023 that relates to assets acquired from Holly in 2008);
   
Holly PTTA (pipeline, tankage and loading rack throughput agreement expiring in 2024 that relates to the Tulsa east facilities acquired from Sinclair in 2009 and from Holly in March 2010);
   
Holly RPA (pipeline throughput agreement expiring in 2024 that relates to the Roadrunner Pipeline acquired from Holly in 2009);
   
Holly ETA (equipment and throughput agreement expiring in 2024 that relates to the Tulsa west facilities acquired from Holly in 2009);
   
Holly NPA (natural gas pipeline throughput agreement expiring in 2024); and
   
Holly ATA (asphalt loading rack throughput agreement expiring in 2025 that relates to the Lovington rack facility acquired from Holly in March 2010).
Under these agreements, Holly 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, 2011, these agreements with Holly will result in minimum annualized payments to us of $133 million.
If Holly 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. A shortfall payment under the Holly PTA and Holly IPA 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 Holly (the “Omnibus Agreement”) we pay Holly an annual administrative fee for the provision by Holly 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 Holly. Also, we reimburse Holly and its affiliates for direct expenses they incur on our behalf.
Related party transactions with Holly are as follows:
 
Revenues received from Holly were $34.1 million and $33.6 million for the three months ended March 31, 2011 and 2010, respectively.
 
Holly charged general and administrative services under the Omnibus Agreement of $0.6 million for the three months ended March 31, 2011 and 2010.
 
We reimbursed Holly for costs of employees supporting our operations of $5 million and $4.2 million for the three months ended March 31, 2011 and 2010, respectively.
 
We distributed $9.7 million and $8.5 million for the three months ended March 31, 2011 and 2010, respectively, to Holly as regular distributions on its common units, and general partner interest, including general partner incentive distributions.
 
Accounts receivable from Holly were $20.4 million and $19 million at March 31, 2011 and December 31, 2010, respectively.

 

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Accounts payable to Holly were $4.3 million and $3.9 million at March 31, 2011 and December 31, 2010, respectively.
 
Revenues for the three months ended March 31, 2011 include $1.1 million of shortfalls billed under the Holly IPA in 2010, as Holly did not exceed its minimum volume commitment in any of the subsequent four quarters. Deferred revenue in the consolidated balance sheets at March 31, 2011 and December 31, 2010, includes $3.8 million and $3.3 million, respectively, relating to the Holly IPA. It is possible that Holly may not exceed its minimum obligations under the Holly IPA to allow Holly to receive credit for any of the $3.8 million deferred at March 31, 2011.
 
We acquired certain storage assets and an asphalt loading rack facility from Holly in March 2010. See Note 2 for a description of this transaction.
Note 10: Partners’ Equity
Holly currently holds 7,290,000 of our common units and the 2% general partner interest, which together constitutes a 34% ownership interest in us.
In May 2010, all of the conditions necessary to end the subordination period for the 937,500 Class B subordinated units originally issued to Alon in connection with our acquisition of assets from Alon in 2005 were met and the units were converted into our common units on a one-for-one basis. These subordinated units were not publicly traded.
Under our registration statement filed with the SEC using a “shelf” registration process, we currently have the ability to raise $860 million through security offerings, 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.
Allocations of Net Income
Net income attributable to Holly Energy Partners, L.P. 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,  
    2011     2010  
    (In thousands)  
General partner interest in net income
  $ 237     $ 169  
General partner incentive distribution
    3,325       2,477  
 
           
Total general partner interest in net income attributable to HEP
  $ 3,562     $ 2,646  
 
           
Cash Distributions
Our general partner, HEP Logistics Holdings, L.P., is entitled to incentive distributions if the amount we distribute with respect to any quarter exceeds specified target levels.

 

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On April 27, 2011, we announced our cash distribution for the first quarter of 2011 of $0.855 per unit. The distribution is payable on all common and general partner units and will be paid May 13, 2011 to all unitholders of record on May 6, 2011.
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,  
    2011     2010  
    (In thousands, except per unit data)  
General partner interest
  $ 453     $ 418  
General partner incentive distribution
    3,325       2,477  
 
           
Total general partner distribution
    3,778       2,895  
Limited partner distribution
    18,877       17,994  
 
           
Total regular quarterly cash distribution
  $ 22,655     $ 20,889  
 
           
Cash distribution per unit applicable to limited partners
  $ 0.855     $ 0.815  
 
           
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 equity since our regular quarterly distributions have exceeded our quarterly net income. Additionally, if the assets contributed and acquired from Holly had occurred while we were not a consolidated variable interest entity of Holly, our acquisition cost in excess of Holly’s historical basis in the transferred assets of $218 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.
Comprehensive Income
We have other comprehensive income resulting from fair value adjustments to our cash flow hedge. Our comprehensive income is as follows:
                 
    Three Months Ended  
    March 31,  
    2011     2010  
    (In thousands)  
Net income
  $ 15,169     $ 10,702  
Other comprehensive income (loss):
               
Change in fair value of cash flow hedge
    1,283       (1,361 )
 
           
Comprehensive income attributable to HEP unitholders
  $ 16,452     $ 9,341  
 
           
Note 11: Supplemental Guarantor/Non-Guarantor Financial Information
Obligations of Holly Energy Partners, L.P. (“Parent”) under the 6.25% Senior Notes and 8.25% 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.
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.

 

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Condensed Consolidating Balance Sheet
                                 
            Guarantor              
March 31, 2011   Parent     Subsidiaries     Eliminations     Consolidated  
    (In thousands)  
ASSETS
                               
Current assets:
                               
Cash and cash equivalents
  $ 2     $ 1,500     $     $ 1,502  
Accounts receivable
          23,475             23,475  
Intercompany accounts receivable (payable)
    (127,271 )     127,271              
Prepaid and other current assets
    211       335             546  
 
                       
Total current assets
    (127,058 )     152,581             25,523  
 
                               
Properties and equipment, net
          440,523             440,523  
Investment in subsidiaries
    564,586             (564,586 )      
Transportation agreements, net
          106,753             106,753  
Goodwill
          49,109             49,109  
Investment in SLC Pipeline
          25,802             25,802  
Other assets
    1,209       3,231             4,440  
 
                       
Total assets
  $ 438,737     $ 777,999     $ (564,586 )   $ 652,150  
 
                       
 
                               
LIABILITIES AND PARTNERS’ EQUITY
                               
Current liabilities:
                               
Accounts payable
  $     $ 10,325     $     $ 10,325  
Accrued interest
    1,514       27             1,541  
Deferred revenue
          9,333             9,333  
Accrued property taxes
          1,738             1,738  
Other current liabilities
    600       479             1,079  
 
                       
Total current liabilities
    2,114       21,902             24,016  
 
                               
Long-term debt
    332,733       182,000             514,733  
Other long-term liabilities
          9,511             9,511  
Partners’ equity
    103,890       564,586       (564,586 )     103,890  
 
                       
Total liabilities and partners’ equity
  $ 438,737     $ 777,999     $ (564,586 )   $ 652,150  
 
                       
Condensed Consolidating Balance Sheet
                                 
            Guarantor              
December 31, 2010   Parent     Subsidiaries     Eliminations     Consolidated  
    (In thousands)  
ASSETS
                               
Current assets:
                               
Cash and cash equivalents
  $ 2     $ 401     $     $ 403  
Accounts receivable
          22,508             22,508  
Intercompany accounts receivable (payable)
    (92,230 )     92,230              
Prepaid and other current assets
    235       540             775  
 
                       
Total current assets
    (91,993 )     115,679             23,686  
 
                               
Properties and equipment, net
          434,950             434,950  
Investment in subsidiaries
    541,262             (541,262 )      
Transportation agreements, net
          108,489             108,489  
Goodwill
          49,109             49,109  
Investment in SLC Pipeline
          25,437             25,437  
Other assets
    1,261       341             1,602  
 
                       
Total assets
  $ 450,530     $ 734,005     $ (541,262 )   $ 643,273  
 
                       
 
                               
LIABILITIES AND PARTNERS’ EQUITY
                               
Current liabilities:
                               
Accounts payable
  $     $ 10,238     $     $ 10,238  
Accrued interest
    7,498       19             7,517  
Deferred revenue
          10,437             10,437  
Accrued property taxes
          1,990             1,990  
Other current liabilities
    1,011       251             1,262  
 
                       
Total current liabilities
    8,509       22,935             31,444  
 
                               
Long-term debt
    332,649       158,999             491,648  
Other long-term liabilities
          10,809             10,809  
Partners’ equity
    109,372       541,262       (541,262 )     109,372  
 
                       
Total liabilities and partners’ equity
  $ 450,530     $ 734,005     $ (541,262 )   $ 643,273  
 
                       

 

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Condensed Consolidating Statement of Income
                                 
            Guarantor              
Three months ended March 31, 2011   Parent     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 (loss) before income taxes
    15,169       22,270       (22,042 )     15,397  
State income tax
          (228 )           (228 )
 
                       
Net income
  $ 15,169     $ 22,042     $ (22,042 )   $ 15,169  
 
                       
Condensed Consolidating Statement of Income
                                 
            Guarantor              
Three months ended March 31, 2010   Parent     Subsidiaries     Eliminations     Consolidated  
    (In thousands)  
Revenues:
                               
Affiliates
  $     $ 33,597     $     $ 33,597  
Third parties
          7,099             7,099  
 
                       
 
          40,696             40,696  
 
                               
Operating costs and expenses:
                               
Operations
          13,060             13,060  
Depreciation and amortization
          7,210             7,210  
General and administrative
    1,801       762             2,563  
 
                       
 
    1,801       21,032               22,833  
 
                       
Operating income (loss)
    (1,801 )     19,664             17,863  
 
                               
Equity in earnings of subsidiaries
    17,485             (17,485 )      
Equity in earnings of SLC Pipeline
          481             481  
Interest income (expense)
    (4,982 )     (2,559 )           (7,541 )
Other
          (7 )           (7 )
 
                       
 
    12,503       (2,085 )     (17,485 )     (7,067 )
 
                       
Income (loss) before income taxes
    10,702       17,579       (17,485 )     10,796  
State income tax
          (94 )           (94 )
 
                       
Net income
  $ 10,702     $ 17,485     $ (17,485 )   $ 10,702  
 
                       

 

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Condensed Consolidating Statement of Cash Flows
                                 
            Guarantor              
Three months ended March 31, 2011   Parent     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 restricted grants
    (399 )                 (399 )
Deferred financing costs
          (3,044 )           (3,044 )
 
                       
 
    (22,604 )     19,956             (2,648 )
 
                       
 
                               
Cash and cash equivalents
                               
Increase (decrease) for the period
          1,099             1,099  
Beginning of period
    2       401             403  
 
                       
End of period
  $ 2     $ 1,500     $     $ 1,502  
 
                       
Condensed Consolidating Statement of Cash Flows
                                 
            Guarantor              
Three months ended March 31, 2010   Parent     Subsidiaries     Eliminations     Consolidated  
    (in thousands)  
 
                               
Cash flows from operating activities
  $ (69,523 )   $ 88,246     $     $ 18,723  
 
                               
Cash flows from investing activities
                               
Additions to properties and equipment
          (1,911 )           (1,911 )
Acquisition of assets from Holly Corporation
          (37,234 )           (37,234 )
 
                       
 
          (39,145 )           (39,145 )
 
                       
 
                               
Cash flows from financing activities
                               
Net repayments under credit agreement
          (35,000 )           (35,000 )
Net proceeds from issuance of senior notes
    147,540                     147,540  
Distributions to HEP unitholders
    (20,506 )                 (20,506 )
Purchase price in excess of transferred basis in assets acquired from Holly Corporation
    (55,766 )                 (55,766 )
Purchase of units for restricted grants
    (1,745 )                 (1,745 )
 
                       
 
    69,523       (35,000 )           34,523  
 
                       
 
                               
Cash and cash equivalents
                               
Increase (decrease) for the period
          14,101             14,101  
Beginning of period
    2       2,506             2,508  
 
                       
End of period
  $ 2     $ 16,607     $     $ 16,609  
 
                       

 

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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 HEP and its consolidated subsidiaries or to HEP or an individual subsidiary and not to any other person.
OVERVIEW
Holly Energy Partners, L.P. is a Delaware limited partnership. We own and operate petroleum product and crude oil pipeline and terminal, tankage and loading rack facilities that support Holly Corporation’s (“Holly”) refining and marketing operations in west Texas, New Mexico, Utah, Oklahoma, Idaho and Arizona. Holly and its subsidiaries currently own a 34% 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”) Big Spring 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 refined products and other hydrocarbons and storing 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.
2010 Acquisitions
Tulsa East / Lovington Storage Asset Transaction
On March 31, 2010, we acquired from Holly certain storage assets for $93 million, consisting of hydrocarbon storage tanks having approximately 2 million barrels of storage capacity, a rail loading rack and a truck unloading rack located at Holly’s Tulsa refinery east facility and an asphalt loading rack facility located at Holly’s Navajo refinery facility in Lovington, New Mexico.
Agreements with Holly Corporation and Alon
We serve Holly’s refineries in New Mexico, Utah and Oklahoma under the following long-term pipeline and terminal, tankage and throughput agreements:
   
Holly PTA (pipelines and terminals throughput agreement expiring in 2019 that relates to assets contributed to us by Holly upon our initial public offering in 2004);
   
Holly IPA (intermediate pipelines throughput agreement expiring in 2024 that relates to assets acquired from Holly in 2005 and 2009);
   
Holly CPTA (crude pipelines and tankage throughput agreement expiring in 2023 that relates to assets acquired from Holly in 2008);
   
Holly PTTA (pipeline, tankage and loading rack throughput agreement expiring in 2024 that relates to the Tulsa east facilities acquired from Sinclair in 2009 and from Holly in March 2010);
   
Holly RPA (pipeline throughput agreement expiring in 2024 that relates to the Roadrunner Pipeline acquired from Holly in 2009);
   
Holly ETA (equipment and throughput agreement expiring in 2024 that relates to the Tulsa west facilities acquired from Holly in 2009);
   
Holly NPA (natural gas pipeline throughput agreement expiring in 2024); and
   
Holly ATA (asphalt loading rack throughput agreement expiring in 2025 that relates to the Lovington rack facility acquired from Holly in March 2010).

 

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Under these agreements, Holly 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, 2011, these agreements with Holly will result in minimum annualized payments to us of $133 million.
We also have a pipelines and terminals agreement with Alon expiring in 2020 under which Alon has agreed to transport on our pipelines and throughput through our terminals volumes of refined products that result in a minimum level of annual revenue that is also subject to annual tariff rate adjustments.
We have a capacity lease agreement with Alon under which we lease Alon space on our Orla to El Paso pipeline for the shipment of up to 17,500 barrels of refined product per day. The terms under this agreement expire beginning in 2012 through 2018.
As of March 31, 2011, contractual minimums under our long-term service agreements are as follows:
                 
    Minimum Annualized          
    Commitment          
Agreement   (In millions)     Year of Maturity   Contract Type
 
               
Holly PTA
  $ 43.7     2019   Minimum revenue commitment
Holly IPA
    20.7     2024   Minimum revenue commitment
Holly CPTA
    28.4     2023   Minimum revenue commitment
Holly PTTA
    27.2     2024   Minimum revenue commitment
Holly RPA
    9.2     2024   Minimum revenue commitment
Holly ETA
    2.7     2024   Minimum revenue commitment
Holly ATA
    0.5     2025   Minimum revenue commitment
Holly NPA
    0.6     2024   Minimum revenue commitment
Alon PTA
    23.4     2020   Minimum volume commitment
Alon capacity lease
    6.4     Various   Capacity lease
 
             
 
               
Total
  $ 162.8          
 
             
A significant reduction in revenues under these agreements would have a material adverse effect on our results of operations.
Under certain provisions of an omnibus agreement (“Omnibus Agreement”) that we have with Holly, we pay Holly an annual administrative fee, currently $2.3 million, for the provision by Holly 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 Holly. We also reimburse Holly and its affiliates for direct expenses they incur on our behalf.

 

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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, 2011 and 2010.
                         
    Three Months Ended     Change  
    March 31,     from  
    2011     2010     2010  
    (In thousands, except per unit data)  
Revenues
                       
Pipelines:
                       
Affiliates — refined product pipelines
  $ 9,858     $ 11,480     $ (1,622 )
Affiliates — intermediate pipelines
    4,633       5,792       (1,159 )
Affiliates — crude pipelines
    9,321       9,405       (84 )
 
                 
 
    23,812       26,677       (2,865 )
Third parties — refined product pipelines
    9,155       5,404       3,751  
 
                 
 
    32,967       32,081       886  
Terminals and loading racks:
                       
Affiliates
    10,295       6,920       3,375  
Third parties
    1,755       1,695       60  
 
                 
 
    12,050       8,615       3,435  
 
                 
Total revenues
    45,017       40,696       4,321  
 
                       
Operating costs and expenses
                       
Operations
    12,796       13,060       (264 )
Depreciation and amortization
    7,640       7,210       430  
General and administrative
    1,363       2,563       (1,200 )
 
                 
 
    21,799       22,833       (1,034 )
 
                 
 
                       
Operating income
    23,218       17,863       5,355  
 
                       
Equity in earnings of SLC Pipeline
    740       481       259  
Interest income
          3       (3 )
Interest expense, including amortization
    (8,549 )     (7,544 )     (1,005 )
Other
    (12 )     (7 )     (5 )
 
                 
 
    (7,821 )     (7,067 )     (754 )
 
                 
 
                       
Income before income taxes
    15,397       10,796       4,601  
 
                       
State income tax
    (228 )     (94 )     (134 )
 
                 
 
                       
Net income
    15,169       10,702       4,467  
 
                       
Less general partner interest in net income, including incentive distributions (1)
    3,562       2,646       916  
 
                 
 
                       
Limited partners’ interest in net income
  $ 11,607     $ 8,056     $ 3,551  
 
                 
 
                       
Limited partners’ earnings per unit — basic and diluted (1)
  $ 0.53     $ 0.36     $ 0.17  
 
                 
 
                       
Weighted average limited partners’ units outstanding
    22,079       22,079        
 
                 
EBITDA (2)
  $ 31,586     $ 25,547     $ 6,039  
 
                 
Distributable cash flow (3)
  $ 20,772     $ 20,159     $ 613  
 
                 
 
                       
Volumes (bpd)
                       
Pipelines:
                       
Affiliates — refined product pipelines
    77,218       93,382       (16,164 )
Affiliates — intermediate pipelines
    68,617       79,118       (10,501 )
Affiliates — crude pipelines
    136,257       134,889       1,368  
 
                 
 
    282,092       307,389       (25,297 )
Third parties — refined product pipelines
    48,528       30,835       17,693  
 
                 
 
    330,620       338,224       (7,604 )
Terminals and loading racks:
                       
Affiliates
    157,932       163,796       (5,864 )
Third parties
    40,356       34,843       5,513  
 
                 
 
    198,288       198,639       (351 )
 
                 
Total for pipelines and terminal assets (bpd)
    528,908       536,863       (7,955 )
 
                 

 

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(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,  
    2011     2010  
    (In thousands)  
 
               
Net income
  $ 15,169     $ 10,702  
 
               
Add (subtract):
               
Interest expense
    8,259       5,886  
Amortization of discount and deferred debt issuance costs
    290       194  
Increase in interest expense — change in fair value of interest rate swaps and swap settlement costs
          1,464  
Interest income
          (3 )
State income tax
    228       94  
Depreciation and amortization
    7,640       7,210  
 
           
 
               
EBITDA
  $ 31,586     $ 25,547  
 
           
(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 equity in excess cash flows over earnings of SLC Pipeline, 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.

 

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Set forth below is our calculation of distributable cash flow.
                 
    Three Months Ended  
    March 31,  
    2011     2010  
    (In thousands)  
 
               
Net income
  $ 15,169     $ 10,702  
 
               
Add (subtract):
               
Depreciation and amortization
    7,640       7,210  
Amortization of discount and deferred debt issuance costs
    290       194  
 
               
Increase in interest expense — change in fair value of interest rate swaps and swap settlement costs
          1,464  
Equity in excess cash flows over earnings of SLC Pipeline
    6       178  
Increase (decrease) in deferred revenue
    (1,104 )     1,108  
Maintenance capital expenditures*
    (1,229 )     (697 )
 
           
 
               
Distributable cash flow
  $ 20,772     $ 20,159  
 
           
*  
Maintenance capital expenditures are capital expenditures made to replace partially or fully depreciated assets in order to maintain the existing operating capacity of our assets and to extend their useful lives. Maintenance capital expenditures include expenditures required to maintain equipment reliability, tankage and pipeline integrity, safety and to address environmental regulations.
                 
    March 31,     December 31,  
    2011     2010  
    (In thousands)  
Balance Sheet Data
               
 
               
Cash and cash equivalents
  $ 1,502     $ 403  
Working capital
  $ 1,507     $ (7,758 )
Total assets
  $ 652,150     $ 643,273  
Long-term debt
  $ 514,733     $ 491,648  
Partners’ equity (4)
  $ 103,890     $ 109,372  
(4)  
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 Holly had occurred while we were not a consolidated variable interest entity of Holly, our acquisition cost in excess of Holly’s historical basis in the transferred assets of $218 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.

 

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Results of Operations — Three Months Ended March 31, 2011 Compared with Three Months Ended March 31, 2010
Summary
Net income for the three months ended March 31, 2011 was $15.2 million, a $4.5 million increase compared to the three months ended March 31, 2010. This increase in overall earnings is due principally to earnings attributable to our March 2010 asset acquisitions and an increase in previously deferred revenue realized.
Revenues for the three months ended March 31, 2011 include the recognition of $3.6 million of prior shortfalls billed to shippers in 2010 as they did not meet their minimum volume commitments in any of the subsequent four quarters. Revenues of $2.5 million relating to deficiency payments associated with certain guaranteed shipping contracts were deferred during the three months ended March 31, 2011. Such deferred revenue will be recognized in earnings either as payment for shipments in excess of guaranteed levels or in 2012 when shipping rights expire unused after a twelve-month period.
Revenues
Total revenues for the three months ended March 31, 2011 were $45 million, a $4.3 million increase compared to the three months ended March 31, 2010. This is due principally to revenues attributable to our March 2010 asset acquisitions and a $1.1 million increase in previously deferred revenue realized. Overall pipeline shipments were down slightly from the first quarter of 2010, reflecting an 8% decrease in affiliate pipeline shipments that were offset significantly by an increase in third-party pipeline shipments.
Related-party pipeline and throughput volumes were down during the current year first quarter as a result of downtime at Holly’s Navajo refinery following a plant-wide power outage in late January and a delay in the process of restoring production to planned operating levels during February as a result of inclement weather. Also, production levels at the Navajo refinery were also down during the first quarter of 2010 as a result of planned project work.
Revenues from our refined product pipelines were $19 million, an increase of $2.1 million compared to the three months ended March 31, 2010. This increase is due principally to a $1.7 million increase in previously deferred revenue realized. Volumes shipped on our refined product pipelines averaged 125.7 thousand barrels per day (“mbpd”) compared to 124.2 mbpd for the same period last year.
Revenues from our intermediate pipelines were $4.6 million, a decrease of $1.2 million compared to the three months ended March 31, 2010. This includes a $0.6 million decrease in previously deferred revenue realized. Shipments on our intermediate product pipeline system decreased to an average of 68.6 mbpd compared to 79.1 mbpd for the same period last year.
Revenues from our crude pipelines were $9.3 million, a decrease of $0.1 million compared to the three months ended March 31, 2010. Volumes on our crude pipelines averaged 136.3 mbpd compared to 134.9 mbpd for the same period last year.
Revenues from terminal, tankage and loading rack fees were $12.1 million, an increase of $3.4 million compared to the three months ended March 31, 2010. This increase is due primarily to $3.5 million in revenues attributable to our Tulsa storage and rack facilities acquired from Holly in March 2010. Refined products terminalled in our facilities decreased to an average of 198.3 mbpd compared to 198.6 mbpd for the same period last year.
Operations Expense
Operations expense for the three months ended March 31, 2011 decreased by $0.3 million compared to the three months ended March 31, 2010. This decrease was due principally to lower maintenance costs incurred during the current year.

 

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Depreciation and Amortization
Depreciation and amortization for the three months ended March 31, 2011 increased by $0.4 million compared to the three months ended March 31, 2010. This was due to increased depreciation attributable to our March 2010 asset acquisitions and capital projects.
General and Administrative
General and administrative costs for the three months ended March 31, 2011 decreased by $1.2 million compared to the three months ended March 31, 2010 which included professional fees and costs incurred as a result of our asset acquisitions from Holly.
Equity in Earnings of SLC Pipeline
Our equity in earnings of the SLC Pipeline was $0.7 million and $0.5 million for the three months ended March 31, 2011 and 2010, respectively.
Interest Expense
Interest expense for the three months ended March 31, 2011 totaled $8.5 million, an increase of $1 million compared to the three months ended March 31, 2010. This increase reflects interest on our 8.25% senior notes issued in March 2010. Additionally, interest expense for the three months ended March 31, 2010 include fair value adjustments of $1.5 million attributable to interest rate swaps settled in the first quarter of 2010. Excluding the effects of the 2010 fair value adjustments, our aggregate effective interest rate was 6.8% for the three months ended March 31, 2011 compared to 5.7% for 2010.
State Income Tax
We recorded state income taxes of $0.2 million and $0.1 million for the three months ended March 31, 2011 and 2010, respectively, which are solely attributable to the Texas margin tax.
LIQUIDITY AND CAPITAL RESOURCES
Overview
During the quarter ended March 31, 2011, we received advances totaling $30 million and repaid $7 million, resulting in net borrowings of $23 million under our $275 million senior secured revolving credit facility (the “Credit Agreement”) and an outstanding balance of $182 million at March 31, 2011. As of March 31, 2011, we had no working capital borrowings.
The Credit Agreement is available to fund capital expenditures, investments, acquisitions, distribution payments and working capital and for general partnership purposes. It is also available to fund letters of credit up to a $50 million sub-limit and to fund distributions to unitholders up to a $30 million sub-limit.
In March 2010, we issued $150 million in aggregate principal amount of 8.25% senior notes maturing March 15, 2018 (the “8.25% Senior Notes”). A portion of the $147.5 million in net proceeds received was used to fund our $93 million purchase of the Tulsa and Lovington storage assets from Holly on March 31, 2010. Additionally, we used a portion to repay $42 million in outstanding Credit Agreement borrowings, with the remaining proceeds available for general partnership purposes, including working capital and capital expenditures. In addition, we have outstanding $185 million in aggregate principal amount of 6.25% senior notes maturing March 1, 2015 (the “6.25% Senior Notes”) that are registered with the SEC.
Under our registration statement filed with the SEC using a “shelf” registration process, we currently have the ability to raise $860 million through security offerings, 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.

 

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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 2011 we paid regular quarterly cash distributions of $0.845 on all units in an aggregate amount of $22.2 million. Included in these distributions were $3.1 million of incentive distribution payments to the general partner.
Cash and cash equivalents increased by $1.1 million during the three months ended March 31, 2011. The cash flows provided by operating activities of $15.2 million exceeded the combined cash flows used for investing and financing activities of $11.5 million and $2.6 million, respectively. Working capital increased by $9.3 million to $1.5 million during the three months ended March 31, 2011.
Cash Flows — Operating Activities
Cash flows from operating activities decreased by $3.5 million from $18.7 million for the three months ended March 31, 2010 to $15.2 million for the three months ended March 31, 2011. This decrease is due principally to interest payments attributable to the 8.25% Senior Notes.
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 $3.6 million during the three months ended March 31, 2010 related to shortfalls that subsequently expired without recapture and were recognized as revenue during the three months ended March 31, 2011. Another $2.5 million is included in our accounts receivable at March 31, 2011 related to shortfalls that occurred during the first quarter of 2011.
Cash Flows — Investing Activities
Cash flows used for investing activities decreased by $27.6 million from $39.1 million for the three months ended March 31, 2010 to $11.5 million for the three months ended March 31, 2011. During the three months ended March 31, 2011 and 2010, we invested $11.5 million and $1.9 million in additions to properties and equipment, respectively. Additionally in March 2010, we acquired storage assets from Holly for $37.2 million.
Cash Flows — Financing Activities
Cash flows used for financing activities were $2.6 million compared to cash provided by financing activities of $34.5 million for the three months ended March 31, 2010, a decrease of $37.1 million. During the three months ended March 31, 2011, we received $30 million and repaid $7 million in advances under the Credit Agreement, we paid $22.2 million in regular quarterly cash distributions to our general and limited partners, paid $3 million in financing costs to amend our previous credit agreement and paid $0.4 million for the purchase of common units for recipients of our restricted unit incentive grants. For the three months ended March 31, 2010, we received $33 million and repaid $68 million in advances under the Credit Agreement. We also received $147.5 million in net proceeds upon the issuance of the 8.25% Senior Notes. Additionally during the three months ended March 31, 2010, we paid $20.5 million in regular quarterly cash distributions to our general and limited partners, paid $55.8 million in excess of Holly’s transferred basis in the storage assets acquired in March 2010 and paid $1.7 million for the purchase of common units for recipients of restricted grants.
Capital Requirements
Our pipeline and terminalling operations are capital intensive, requiring investments to maintain, expand, upgrade or enhance existing operations and to meet environmental and operational regulations. Our capital requirements 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.

 

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Each year the HLS board of directors 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 2011 capital budget is comprised of $5.8 million for maintenance capital expenditures and $20.1 million for expansion capital expenditures.
We are currently constructing five interconnecting pipelines between Holly’s Tulsa east and west refining facilities. The project is expected to cost approximately $35 million with completion in the summer of 2011. We are currently negotiating terms for a long-term agreement with Holly to transfer intermediate products via these pipelines that will commence upon completion of the project. In the event that we are unable to obtain such an agreement, Holly will reimburse us for the cost of the pipelines.
We have an option agreement with Holly, granting us an option to purchase Holly’s 75% equity interest in UNEV Pipeline, LLC (“UNEV Pipeline”), a joint venture pipeline currently under construction that will be capable of transporting refined petroleum products from Salt Lake City, Utah to Las Vegas, Nevada. Under this agreement, we have an option to purchase Holly’s equity interest in the UNEV Pipeline, effective for a 180-day period commencing when the UNEV Pipeline becomes operational, at a purchase price equal to Holly’s investment in the joint venture pipeline, plus interest at 7% per annum. The initial capacity of the pipeline will be 62,000 bpd, with the capacity for further expansion to 120,000 bpd. The current total construction cost of the pipeline project including terminals is expected to be approximately in the $340 million range. This includes the construction of ethanol blending and storage facilities at the Cedar City terminal. Holly’s share of this estimated cost is the $255 million range and is exclusive of the 7% per annum interest cost under our option to purchase Holly’s 75% interest in the UNEV Pipeline. The pipeline is in the final construction phase and is expected to be mechanically complete in the third quarter of 2011.
We expect that our currently planned sustaining and maintenance capital expenditures as well as expenditures for acquisitions and capital development projects such as 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 may be limited, especially the UNEV Pipeline. 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.
Credit Agreement
We have a $275 million Credit Agreement that is available to fund capital expenditures, investments, acquisitions, distribution payments and working capital and for general partnership purposes. It is also available to fund letters of credit up to a $50 million sub-limit and to fund distributions to unitholders up to a $30 million sub-limit. In February 2011, we amended our previous credit agreement (expiring in August 2011), slightly, reducing the size of the credit facility from $300 million to $275 million. The size was reduced based on management’s review of past and forecasted utilization of the facility. The Credit Agreement expires in February 2016; however, in the event that the 6.25% Senior Notes are not repurchased, refinanced, extended or repaid prior to September 1, 2014, the Credit Agreement shall expire on that date.

 

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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., our general partner, and guaranteed by our material, wholly-owned subsidiaries. Any recourse to HEP Logistics Holdings, L.P. 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.
Indebtedness under the Credit Agreement bears interest, at our option, at either (a) the reference rate as announced by the administrative agent plus an applicable margin (ranging from 1.00% to 2.00%) or (b) at a rate equal to the London Interbank Offered Rate (“LIBOR”) plus an applicable margin (ranging from 2.00% to 3.00%). In each case, the applicable margin is based upon the ratio of our funded debt (as defined in the Credit Agreement) to EBITDA (earnings before interest, taxes, depreciation and amortization, as defined in the Credit Agreement). We incur a commitment fee on the unused portion of the Credit Agreement at an annual rate ranging from 0.375% to 0.50% based upon the ratio of our funded debt to EBITDA for the four most recently completed fiscal quarters.
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
The 6.25% 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 Holdings, L.P., our general partner, and guaranteed by our wholly-owned subsidiaries. However, any recourse to HEP Logistics Holdings, L.P. would be limited to the extent of its assets, which other than its investment in us, are not significant.
The carrying amounts of our long-term debt are as follows:
                 
    March 31,     December 31,  
    2011     2010  
    (In thousands)  
Credit Agreement
  $ 182,000     $ 159,000  
 
               
6.25% Senior Notes
               
Principal
    185,000       185,000  
Unamortized discount
    (1,489 )     (1,584 )
Unamortized premium — dedesignated fair value hedge
    1,357       1,444  
 
           
 
    184,868       184,860  
 
           
 
               
8.25% Senior Notes
               
Principal
    150,000       150,000  
Unamortized discount
    (2,135 )     (2,212 )
 
           
 
    147,865       147,788  
 
           
 
               
Total long-term debt
  $ 514,733     $ 491,648  
 
           
See “Risk Management” for a discussion of our interest rate swap.

 

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Contractual Obligations
During the three months ended March 31, 2011, we had net borrowings of $23 million resulting in $182 million of borrowings outstanding under the Credit Agreement at March 31, 2011.
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 low in recent years and did not have a material impact on our results of operations for the three months ended March 31, 2011 and 2010.
A 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. Historically, the PPI has increased an average of 3% annually over the past 5 calendar years. This is no indication that PPI increases will be realized in the near future. Furthermore, certain of our long-term contracts have provisions that limit the level of annual PPI percentage rate increases.
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, Holly agreed to indemnify us up to certain aggregate amounts for any environmental noncompliance and remediation liabilities associated with assets transferred to us and occurring or existing prior to the date of such transfers. The transfers that are covered by the agreement include the refined product pipelines, terminals and tanks transferred by Holly’s subsidiaries in connection with our initial public offering in July 2004, the intermediate pipelines acquired in July 2005, the crude pipelines and tankage assets acquired in 2008, and the asphalt loading rack facility acquired in March 2010. The Omnibus Agreement provides environmental indemnification of up to $15 million for the assets transferred to us, other than the crude pipelines and tankage assets, plus an additional $2.5 million for the intermediate pipelines acquired in July 2005. Except as described below, Holly’s indemnification obligations described above will remain in effect for an asset for ten years following the date it is transferred to us. The Omnibus Agreement also provides an additional $7.5 million of indemnification through 2023 for environmental noncompliance and remediation liabilities specific to the crude pipelines and tankage assets. Holly’s indemnification obligations described above 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.

 

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Under provisions of the Holly ETA and Holly PTTA, Holly will indemnify us for environmental liabilities arising from our pre-ownership operations of the Tulsa west loading rack facilities acquired from Holly in August 2009, the Tulsa logistics and storage assets acquired from Sinclair in December 2009 and the Tulsa east storage tanks and loading racks acquired from Holly in March 2010. Additionally, Holly agreed to indemnify us for any liabilities arising from Holly’s operation of the loading racks under the Holly ETA.
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 Holly. Certain of these projects were underway prior to our purchase and represent liabilities of Holly Corporation as the obligation for future remediation activities was retained by Holly. At March 31, 2011, we have an accrual of $0.3 million that relates to environmental clean-up projects for which we have assumed liability. The remaining projects, including assessment and monitoring activities, are covered under the Holly environmental indemnification discussed above and represent liabilities of Holly Corporation.
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. We consider the following 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
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, 2010. 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 assessing contingent liabilities for probable losses. There have been no changes to these policies in 2011. 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.
RISK MANAGEMENT
We use interest rate swaps (derivative instruments) to manage our exposure to interest rate risk.
As of March 31, 2011, 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 million Credit Agreement advance. This interest rate swap effectively converts our $155 million LIBOR based debt to fixed rate debt having an interest rate of 3.74% plus an applicable margin currently 2.50%, which equals an effective interest rate of 6.24% as of March 31, 2011. This swap contract matures in February 2013.
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 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 million of our variable rate debt. Any ineffectiveness is reclassified from accumulated other comprehensive loss to interest expense. To date, we have had no ineffectiveness on our cash flow hedge.

 

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Additional information on our interest rate swap is as follows:
                         
    Balance Sheet           Location of Offsetting   Offsetting  
Derivative Instrument   Location   Fair Value     Balance   Amount  
    (In thousands)  
March 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
  $ 8,743    
Accumulated other
comprehensive loss
  $ 8,743  
 
                   
 
                       
December 31, 2010
                       
 
                       
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
  $ 10,026    
Accumulated other
comprehensive loss
  $ 10,026  
 
                   
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, 2011, we had an outstanding principal balance on our 6.25% Senior Notes and 8.25% Senior Notes of $185 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, 2011, the fair value of our 6.25% Senior Notes and 8.25% Senior Notes were $185 million and $160.5 million, respectively. We estimate a hypothetical 10% change in the yield-to-maturity applicable to the 6.25% Senior Notes and 8.25% Senior Notes at March 31, 2011 would result in a change of approximately $4 million and $6 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, 2011, borrowings outstanding under the Credit Agreement were $182 million. By means of our cash flow hedge, we have effectively converted the variable rate on $155 million of outstanding borrowings to a fixed rate of 6.24%.
At March 31, 2011, 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 Risks
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. We utilize derivative instruments to hedge our interest rate exposure, also 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, 2011.
(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 6.  
Exhibits
The Exhibit Index on page 37 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: April 29, 2011
      /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)    

 

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Exhibit Index
         
Exhibit    
Number   Description
       
 
  10.1    
Second Amended and Restated Credit Agreement dated February 14, 2011, among Holly Energy Partners — Operating, L.P., Wells Fargo Bank, N.A., as administrative agent and an issuing bank, Union Bank, N.A., as syndication agent, BBVA Compass Bank and U.S. Bank N.A., as co-documentation agents, and certain other lenders (incorporated by reference to Exhibit 10.1 of Registrant’s Form 8-K Current Report dated February 18, 2011, File No. 1-32225).
       
 
  10.2 *  
Form of Holly Energy Partners, L.P. Indemnification Agreement to be entered into with officers and directors of Holly Logistic Services, L.L.C. (incorporated by reference to Exhibit 10.2 of Registrant’s Form 8-K Current Report dated February 18, 2011, File No. 1-32225).
       
 
  10.3 *  
Holly Energy Partners, L.P. Change in Control Agreement Policy (incorporated by reference to Exhibit 10.3 of Registrant’s Form 8-K Current Report dated February 18, 2011, File No. 1-32225).
       
 
  10.4 *  
Form of Change in Control Agreement (incorporated by reference to Exhibit 10.4 of Registrant’s Form 8-K Current Report dated February 18, 2011, File No. 1-32225).
       
 
  10.5    
Second Amendment to Tulsa Refinery Interconnects Term Sheet dated March 31, 2011 (incorporated by reference to Exhibit 10.1 of Registrant’s Form 8-K Current Report dated March 31, 2011, 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.
+  
Filed herewith.
 
++  
Furnished herewith.
 
*  
Constitutes management contracts or compensatory plans or arrangements.

 

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