UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 20082009

OR

[    ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from _______________________ to __________________________

Commission File Number 1-16417

NUSTAR ENERGY L.P.

(Exact name of registrant as specified in its charter)

 

Delaware 74-2956831

(State or other jurisdiction of

incorporation or organization)

 

(I.R.S. Employer

Identification No.)

2330 North Loop 1604 West

San Antonio, Texas

 78248
San Antonio, Texas(Zip Code)
(Address of principal executive offices) (Zip Code)

Registrant’s telephone number, including area code (210) 918-2000

Securities registered pursuant to Section 12(b) of the Act:Common units representing partnership interests listed on the New York Stock Exchange.

Securities registered pursuant to 12(g) of the Act: None.

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

Yes [X] No [    ]

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act.

Yes [    ] No [X]

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 [X] No [    ]

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes [    ] No [    ]

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§229.405 of this chapter) is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. [    ]

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-2Rule12b-2 of the Exchange Act (Check one):

 

Large accelerated filer [X][X]  Accelerated filer [    ]
Non-accelerated filer[    ]  (Do not check if a smaller reporting company)  Smaller reporting company[    ]

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes [    ] No [X]

The aggregate market value of the common units held by non-affiliates was approximately $2,097$2,389 million based on the last sales price quoted as of June 30, 2008,2009, the last business day of the registrant’s most recently completed second quarter.

The number of common units outstanding as of February 1, 20092010 was 54,460,549.60,210,549.

 

 

 


TABLE OF CONTENTS

 

PART I

Items 1., 1A. & 2.

  

Business, Risk Factors and Properties

  3
  

Recent Developments

  4
  

Organizational Structure

  4
  

Segments

  6
  

Employees

  1920
  

Rate Regulation

  20
  

Environmental and Safety RegulationRegulations

  20
  

Risk Factors

  2423
  

Properties

  33

ItemItems 1B.

  

Unresolved Staff Comments

  34

Item 3.

  

Legal Proceedings

  34

Item 4.

  

Submission of Matters to a Vote of Security Holders

  3536
PART II

Item 5.

  

Market for Registrant’s Common Units, Related Unitholder Matters and Issuer Purchases of Common Units

  3637

Item 6.

  

Selected Financial Data

  3738

Item 7.

  

Management’s Discussion and Analysis of Financial Condition and Results of Operations

  3839

Item 7A.

  

Quantitative and Qualitative DisclosuresDisclosure About Market Risk

  5857

Item 8.

  

Financial Statements and Supplementary Data

  6160

Item 9.

  

Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

  111109

Item 9A.

  

Controls and Procedures

  111109

Item 9B.

  

Other Information

  111109
PART III

Item 10.

  

Directors, and Executive Officers of the Registrantand Corporate Governance

  112110

Item 11.

  

Executive Compensation

  115114

Item 12.

  

Security Ownership of Certain Beneficial Owners and Management and Related Unitholder Matters

  150148

Item 13.

  

Certain Relationships and Related Transactions and Director Independence

  152150

Item 14.

  

Principal Accountant Fees and Services

  155153
PART IV

Item 15.

  

Exhibits and Financial Statement Schedules

  157155

Signatures

  166162

PART I

Unless otherwise indicated, the terms “NuStar Energy L.P.,” “the Partnership,” “we,” “our” and “us” are used in this report to refer to NuStar Energy L.P., to one or more of our consolidated subsidiaries or to all of them taken as a whole. In the following Items 1., 1A. and 2., “Business, Risk Factors and Properties,” we make certain forward-looking statements, including statements regarding our plans, strategies, objectives, expectations, intentions and resources. The words “forecasts,” “intends,” “believes,” “expects,” “plans,” “scheduled,” “goal,” “may,” “anticipates,” “estimates” and similar expressions identify forward-looking statements. We do not undertake to update, revise or correct any of the forward-looking information. You are cautioned that such forward-looking statements should be read in conjunction with our disclosures beginning on page 3839 of this report under the heading: “CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION.”

ITEM 1. BUSINESS, RISK FACTORS AND PROPERTIES

OVERVIEW

NuStar Energy L.P. (NuStar Energy), a Delaware limited partnership, completed its initial public offering of common units on April 16, 2001. Our common units are traded on the New York Stock Exchange (NYSE) under the symbol “NS.” Our principal executive offices are located at 2330 North Loop 1604 West, San Antonio, Texas 78248 and our telephone number is (210) 918-2000.

We are engaged in the terminalling and storage of petroleum products, the transportation of petroleum products and anhydrous ammonia, and asphalt and fuels marketing. We manage our operations through the following three operating segments: storage, transportation, and asphalt and fuels marketing. As of December 31, 2008,2009, our assets included:

 

58 refined product terminal facilities providing approximately 61.261.4 million barrels of storage capacity and one crude oil terminal facility providing 4.84.9 million barrels of storage capacity;

60 crude oil storage tanks providing storage capacity of 12.5 million barrels;

5,6795,605 miles of refined product pipelines with 21 associated terminals providing storage capacity of 4.6 million barrels and two tank farms providing storage capacity of 1.2 million barrels;

2,000 miles of anhydrous ammonia pipelines;

812 miles of crude oil pipelines with 16 associated storage tanks providing storage capacity of 1.9 million barrels; and

two asphalt refineries with a combined throughput capacity of 104,000 barrels per day and two associated terminal facilities with a combined storage capacity of 4.75.0 million barrels.

We conduct our operations through our wholly owned subsidiaries, primarily NuStar Logistics, L.P. (NuStar Logistics) and NuStar Pipeline Operating Partnership L.P. (NuPOP). Our revenues include:

 

tariffs for transporting crude oil, refined products and anhydrous ammonia through our pipelines;

fees for the use of our terminals and crude oil storage tanks and related ancillary services; and

sales of asphalt and other refined petroleum products.

Our business strategy is to increase per unit cash distributions to our partners through:

 

continuous improvement of our operations by improving safety and environmental stewardship, cost controls and asset reliability and integrity;

internal growth through enhancing the utilization of our existing assets by expanding our business with current and new customers as well as investments in strategic expansion projects;

external growth from acquisitions that meet our financial and strategic criteria;

complementary operations such as our product marketing and trading organization, which we created to capitalize on opportunities to optimize the use and profitability of our assets; and

growth and improvement of our asphalt operations to benefit from anticipated decreases in overall asphalt supply and higher asphalt margins.

The term ‘‘throughput’’“throughput” as used in this document generally refers to the crude oil or refined product barrels or tons of ammonia, as applicable, that pass through our pipelines, terminals, storage tanks or refineries.

Our internet website address ishttp://www.nustarenergy.com. Information contained on our website is not part of this report. Our annual reports on Form 10-K, quarterly reports on Form 10-Q and current reports on Form 8-K filed with (or furnished to) the Securities and Exchange Commission (SEC) are available on our internet website, free of charge, as soon as reasonably practicable after we file or furnish such material (select the “Investors” link, then the “Financial Reports SEC Filings” link). We also post our corporate governance guidelines, code of business conduct and ethics, code of ethics for senior financial officers and the charters of our board’s committees on our internet website free of charge (select the “Investors” link, then the “Corporate Governance” link). Our governance documents are available in print to any unitholder that makes a written request to Corporate Secretary, NuStar Energy L.P., 2330 North Loop 1604 West, San Antonio, Texas 78248.

RECENT DEVELOPMENTS

On March 20, 2008, we acquired CITGO Asphalt Refining Company’s asphalt operations and assets (the East Coast Asphalt Operations) for approximately $838.5 million. The East Coast Asphalt Operations include a 74,000 barrels-per-day (BPD) asphalt refinery in Paulsboro, New Jersey, a 30,000 BPD asphalt refinery in Savannah, Georgia and three asphalt terminals. The terminals located in Paulsboro, New Jersey, Savannah, Georgia and Wilmington, North Carolina have storage capacities of 3.5 million barrels, 1.2 million barrels, and 0.2 million barrels, respectively.

In April 2008,November 2009, we issued 5,050,8005,750,000 common units representing limited partner interests at a price of $48.75$52.45 per unit. We received net proceeds of $236.2$288.8 million and a contribution of $5.0$6.2 million from our general partner to maintain its 2% general partner interest. The net proceeds were used mainly to repay the $124.0 million balance under our term loan agreement and a portion ofreduce the outstanding principal balance under our revolving credit agreement.

On April 4, 2008, NuStar Logistics issued $350.0 million of 7.65% senior notes for net proceeds of $346.2 million. The net proceeds were used to repay a portion of the outstanding principal balance under our revolving credit agreement.

On December 1, 2008, we agreed to dispose of our interest in the Skelly-Belvieu Pipeline Company, LLC, which owns a liquefied petroleum gas pipeline in Texas, for $36.0 million to Enterprise Products Operating LLC.

ORGANIZATIONAL STRUCTURE

Our operations are managed by NuStar GP, LLC, the general partner of our general partner, NuStar GP, LLC.partner. NuStar GP, LLC, a Delaware limited liability company, is a consolidated subsidiary of NuStar GP Holdings, LLC (NuStar GP Holdings) (NYSE: NSH).

In two separate public offerings in 2006, Valero Energy Corporation (Valero Energy) sold their ownership interest in NuStar GP Holdings. NuStar GP Holdings did not receive any proceeds from either public offering, and Valero Energy's ownership interest in NuStar GP Holdings was reduced to zero.

The following chart depicts our organizational structure at December 31, 2008.2009.

SEGMENTS

Beginning in the second quarter of 2008, we revised the manner in which we internally evaluate our segment performanceOur three reportable business segments are storage, transportation, and made certain organizational changes. As a result, we have changed the way we report our segmental results. All product sales and related costs, including those associated with the East Coast Asphalt Operations, are included in the asphalt and fuels marketing segment. Also, the refined product terminals and crude oil storage tanks segments have been combined into the storage segment and the refined products pipelines and crude oil pipelines have been combined into the transportation segment. Previous periods have been restated to conform to this presentation.

marketing. Detailed financial information about our segments is included in Note 2422 in the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data.”

The following map depicts our operations at December 31, 2008.2009.

STORAGE

Our storage segment includes terminal facilities that provide storage and handling services on a fee basis for petroleum products, specialty chemicals, crude oil and other liquids and crude oil storage tanks used to store and deliver crude oil. In addition, our terminals located on the island of St. Eustatius, the Netherlands Antilles and Point Tupper, Nova Scotia provide services such as pilotage, tug assistance, line handling, launch service, emergency response services and other ship services. As of December 31, 2008,2009, we owned and operated:

 

49 terminals in the United States, with a total storage capacity of approximately 36.336.4 million barrels;

A terminal on the island of St. Eustatius, Netherlands Antilles with a tank capacity of 13.0 million barrels and a transshipment facility;

A terminal located in Point Tupper, Nova Scotia with a tank capacity of 7.4 million barrels and a transshipment facility;

Six terminals located in the United Kingdom and one terminal located in Amsterdam, the Netherlands, having a total storage capacity of approximately 9.39.5 million barrels;

A terminal located in Nuevo Laredo, Mexico; and

60 crude oil and intermediate feedstock storage tanks and related assets in Texas and California with aggregate storage capacity of approximately 12.5 million barrels.

Description of Largest Terminal Facilities

St. Eustatius, Netherlands Antilles.We own and operate a 13.0 million barrel petroleum storage and terminalling facility located on the Netherlands Antilles island of St. Eustatius, the Netherlands Antilles, which is located at a point of minimal deviation from major shipping routes. This facility is capable of handling a wide range of petroleum products, including crude oil and refined products, and it can accommodate the world’s largest tankers for loading and discharging crude oil and other petroleum products. A two-berth jetty, a two-berth monopile with platform and buoy systems, a floating hose station and an offshore single point mooring buoy with loading and unloading capabilities serve the terminal’s customers’ vessels. The St. Eustatius facility has a total of 58 tanks. The fuel oil and petroleum product facilities have in-tank and in-line blending capabilities, while the crude tanks have tank-to-tank blending capability and in-tank mixers. In addition to the storage and blending services at St. Eustatius, this facility has the flexibility to utilize certain storage capacity for both feedstock and refined products to support our atmospheric distillation unit. This unit is capable of processing up to 25,000 barrels per day of feedstock, ranging from condensates to heavy crude oil. We own and operate all of the berthing facilities at the St. Eustatius terminal. Separate fees apply for the use of the berthing facilities, as well as associated services, including pilotage, tug assistance, line handling, launch service, spill response services and other ship services.

Point Tupper, Nova Scotia.We own and operate a 7.4 million barrel terminalling and storage facility located at Point Tupper on the Strait of Canso, near Port Hawkesbury, Nova Scotia, which is located approximately 700 miles from New York City and 850 miles from Philadelphia. This facility is the deepest independent, ice-free marine terminal on the North American Atlantic coast, with access to the East Coast, Canada and the Midwestern United States via the St. Lawrence Seaway and the Great Lakes system. With one of the premier jetty facilities in North America, the Point Tupper facility can accommodate substantially all of the world’s largest, fully laden very large crude carriers and ultra large crude carriers for loading and discharging crude oil, petroleum products and petrochemicals. Crude oil and petroleum product movements at the terminal are fully automated. Separate fees apply for the use of the jetty facility, as well as associated services, including pilotage, tug assistance, line handling, launch service, spill response services and other ship services. We also charter tugs, mooring launches and other vessels to assist with the movement of vessels through the Strait of Canso and the safe berthing of vessels at the terminal facility.

Piney Point, Maryland.Our terminal and storage facility in Piney Point, Maryland is located on approximately 400 acres on the Potomac River. The Piney Point terminal has approximately 5.4 million barrels of storage capacity in 28 tanks and is the closest deep-water facility to Washington, D.C. This terminal competes with other large petroleum terminals in the East Coast water-borne market extending from New York Harbor to Norfolk, Virginia. The terminal currently stores petroleum products consisting primarily of fuel oils and asphalt. The terminal has a dock with a 36-foot draft for tankers and four berths for barges. It also has truck-loading facilities, product-blending capabilities and is connected to a pipeline that supplies residual fuel oil to two power generating stations.

St. James, Louisiana.Our St. James terminal has 29 crude oil storage tanks with a total capacity of approximately 4.9 million barrels. Additionally, the facility has a rail-loading facility and three docks with barge and ship access. The facility is located on almost 900 acres of land, some of which is undeveloped land.

Linden, New Jersey.We own 50% of ST Linden Terminal LLC, which owns a terminal and storage facility in Linden, New Jersey. The terminal is located on a 44-acre facility that provides it with deep-water terminalling capabilities at New York Harbor. This terminal primarily stores petroleum products, including gasoline, jet fuel and fuel oils. The facility has

a total capacity of approximately 4.0 million barrels in 24 tanks and can receive and deliver products via ship, barge and pipeline. The terminal includes two docks and leases a third with draft limits of 36, 26 and 20 feet, respectively.

St. James, Louisiana.    Our St. James terminal has 21 crude oil storage tanks with a total capacity of approximately 4.8 million barrels. Additionally, the facility has a rail-loading facility and three docks with barge and ship access. The facility is located on approximately 220 acres of land on the west bank of the Mississippi River approximately 60 miles west of New Orleans and has an additional 675 acres of undeveloped land.

Terminal Facilities and Crude Oil Storage Tanks

The following table sets forth information about our terminal facilities:

 

Facility

  

Tank

Capacity

  

Number of

Tanks

  

Primary Products Handled

  

Tank

Capacity

  

Number of

Tanks

  Primary Products Handled
  (Barrels)        (Barrels)        

Major U.S. Terminals:

                

Piney Point, MD

  5,404,000    28  

Petroleum products, asphalt

  5,404,000    28    Petroleum products, asphalt
St. James, LA  4,880,000    29    Crude oil and feedstocks

Linden, NJ (a)

  3,957,000    24  

Petroleum products

  3,957,000    24    Petroleum products

St. James, LA

  4,807,000    21  

Crude oil and feedstocks

Selby, CA

  2,829,000    22  

Petroleum products, ethanol

  2,829,000    22    Petroleum products, ethanol
Texas City, TX  2,731,000    73    Chemicals, petrochemicals, petroleum products

Jacksonville, FL

  2,505,000    34  

Petroleum products, asphalt

  2,505,000    34    Petroleum products, asphalt

Texas City, TX

  2,736,000  103  

Chemicals, petrochemicals, petroleum products

Other U.S. Terminals:

                

Montgomery, AL

  162,000      7  

Petroleum products

  162,000    7    Petroleum products

Moundville, AL

  310,000      6  

Petroleum products

  310,000    6    Petroleum products

Los Angeles, CA

  606,000    19  

Petroleum products

  606,000    19    Petroleum products

Pittsburg, CA

  361,000    10  

Asphalt

  361,000    10    Asphalt

Stockton, CA

  802,000    33  

Petroleum products, ethanol, fertilizer

  764,000    29    Petroleum products, ethanol, fertilizer

Colorado Springs, CO

  320,000      7  

Petroleum products, ethanol

  320,000    7    Petroleum products, ethanol

Denver, CO

  100,000      8  

Petroleum products, ethanol

  100,000    8    Petroleum products, ethanol

Bremen, GA

  178,000      8  

Petroleum products

  178,000    8    Petroleum products

Brunswick, GA

  160,000      2  

Fertilizer, pulp liquor

  160,000    2    Fertilizer, pulp liquor

Macon, GA (b)

  307,000    10  

Petroleum products

  307,000    10    Petroleum products

Savannah, GA

  857,000    21  

Petroleum products, caustic

  857,000    21    Petroleum products, caustic

Blue Island, IL

  729,000    15  

Petroleum products, ethanol

  719,000    14    Petroleum products, ethanol

Indianapolis, IN

  366,000    18  

Petroleum products

  366,000    18    Petroleum products

Andrews AFB, MD (b)

  72,000      3  

Petroleum products

  72,000    3    Petroleum products

Baltimore, MD

  825,000    49  

Chemicals, asphalt

  814,000    47    Chemicals, asphalt, petroleum products

Salisbury, MD

  177,000    14  

Petroleum products

  177,000    14    Petroleum products

Wilmington, NC

  206,000      8  

Asphalt

  304,000    12    Asphalt

Linden, NJ

  353,000      9  

Petroleum products

  353,000    9    Petroleum products

Paulsboro, NJ

  69,000      9  

Petroleum products

  69,000    9    Petroleum products

Alamogordo, NM (b)

  120,000      5  

Petroleum products

  120,000    5    Petroleum products

Albuquerque, NM

  245,000    10  

Petroleum products, ethanol

  245,000    10    Petroleum products, ethanol

Rosario, NM

  160,000      8  

Asphalt

  160,000    8    Asphalt

Catoosa, OK

  340,000    24  

Asphalt

  340,000    24    Asphalt

Portland, OR

  1,203,000    32  

Petroleum products, ethanol

  1,203,000    32    Petroleum products, ethanol

Abernathy, TX

  155,000      7  

Petroleum products

  155,000    7    Petroleum products

Amarillo, TX

  255,000      8  

Petroleum products

  255,000    8    Petroleum products

Corpus Christi, TX

  352,000    11  

Petroleum products

  327,000    10    Petroleum products

Edinburg, TX

  267,000      6  

Petroleum products

  267,000    6    Petroleum products

El Paso, TX (c)

  343,000    12  

Petroleum products

  343,000    12    Petroleum products, ethanol

Harlingen, TX

  315,000      7  

Petroleum products

  315,000    7    Petroleum products

Houston, TX (Hobby Airport)

  106,000      4  

Petroleum products

  106,000    4    Petroleum products

Houston, TX

  90,000      6  

Asphalt

  85,000    5    Asphalt

Laredo, TX

  320,000      7  

Petroleum products

  320,000    7    Petroleum products

Placedo, TX

  97,000      4  

Petroleum products

  97,000    4    Petroleum products

San Antonio (east), TX

  148,000      5  

Petroleum products

  148,000    5    Petroleum products

San Antonio (south), TX

  215,000      5  

Petroleum products

  215,000    5    Petroleum products

Southlake, TX

  575,000    12  

Petroleum products, ethanol

Texas City, TX

  125,000    10  

Petroleum products

Facility

  

Tank

Capacity

  

Number of

Tanks

  

Primary Products Handled

  

Tank

Capacity

  

Number of

Tanks

  Primary Products Handled
  (Barrels)        (Barrels)        

Southlake, TX

  575,000    12    Petroleum products, ethanol

Texas City, TX

  125,000    10    Petroleum products

Dumfries, VA

  548,000    14  

Petroleum products, asphalt

  548,000    14    Petroleum products, asphalt

Virginia Beach, VA (b)

  41,000      2  

Petroleum products

  41,000    2    Petroleum products

Tacoma, WA

  359,000    14  

Petroleum products, ethanol

  359,000    14    Petroleum products, ethanol

Vancouver, WA

  328,000    48  

Chemicals

  328,000    48    Chemicals

Vancouver, WA

  408,000      7  

Petroleum products

  408,000    7    Petroleum products
                    

Total U.S. Terminals

  36,313,000  756    36,390,000    729    
                    

Foreign Terminals:

                

St. Eustatius, Netherlands Antilles

  12,996,000    58  

Petroleum products, crude oil

  12,996,000    58    Petroleum products, crude oil and feedstocks

Point Tupper, Canada

  7,364,000    37  

Petroleum products, crude oil

  7,354,000    37    Petroleum products, crude oil and feedstocks

Grays, England

  1,945,000    53  

Petroleum products

  1,956,000    53    Petroleum products

Eastham, England

  2,185,000  162  

Chemicals, petroleum products, animal fats

  2,156,000    162    Chemicals, petroleum products, animal fats

Runcorn, England

  146,000      4  

Molten sulfur

  145,000    4    Molten sulfur

Grangemouth, Scotland

  530,000    46  

Petroleum products, chemicals and molasses

  565,000    47    Petroleum products, chemicals

Glasgow, Scotland

  344,000    16  

Petroleum products

  360,000    16    Petroleum products

Belfast, Northern Ireland

  407,000    41  

Petroleum products

  440,000    41    Petroleum products

Amsterdam, the Netherlands

  3,713,000    42  

Petroleum products

  3,848,000    44    Petroleum products

Nuevo Laredo, Mexico

  34,000      5  

Petroleum products

  34,000    5    Petroleum products
                    

Total Foreign Terminals

  29,664,000  464    29,854,000    467    
                    

 

(a)

We own 50% of this terminal through a joint venture.

(b)

Terminal facility also includes pipelines to U.S. government military base locations.

(c)

We own a 66.67% undivided interest in the El Paso refined product terminal. The tankage capacity and number of tanks represent the proportionate share of capacity attributable to our ownership interest.

During 2008, we sold four of our refined product terminals in Westwego, Louisiana, Tucson, Arizona, Milwaukee, Wisconsin and Reno, Nevada with an aggregate storage capacity of approximately 1.3 million barrels for total proceeds of approximately $9.9 million.

The following table sets forth information about our crude oil storage tanks:

 

Location

  

Capacity

  

Number
of Tanks

  

Mode of

Receipt

  

Mode of

Delivery

    Capacity Numberof Tanks  

Mode of

Receipt

  Mode of

Delivery

  (Barrels)         
  (Barrels)            

Benicia, CA

  3,815,000  16  marine/pipeline  pipeline    3,815,000   16    marine/pipeline  pipeline

Corpus Christi, TX

  4,023,000  26  marine  pipeline    4,023,000   26    marine  pipeline

Texas City, TX

  3,087,000  14  marine  pipeline    3,087,000   14    marine  pipeline

Corpus Christi, TX (North Beach)

  1,600,000    4  marine  pipeline    1,600,000   4    marine  pipeline
                         

Total

  12,525,000  60        12,525,000   60      
                         

The land underlying these crude oil storage tanks is subject to long-term operating leases.

Storage Operations

Revenues for the storage segment include fees for tank storage agreements, in which a customer agrees to pay for a certain amount of storage in a tank over a period of time (storage lease revenues), and throughput agreements, in which a customer pays a fee per barrel for volumes moving through our terminals (throughput revenues). Our terminals also provide blending, additive injections, handling and filtering services. We charge a fee for each barrel of crude oil and certain other feedstocks that we deliver to Valero Energy’sEnergy Corporation (Valero Energy)’s Benicia, Corpus Christi West and Texas City refineries from our crude oil storage tanks. Our facilities at Point Tupper and St. Eustatius charge fees to provide services such as pilotage, tug assistance, line handling, launch service, emergency response services and other ship services.services.

Demand for Refined Petroleum Products

The operations of our refined product terminals depend in large part on the level of demand for products stored in our terminals in the markets served by those assets. The majority of products stored in our terminals are refined petroleum products. Demand for our terminalling services will generally increase or decrease with demand for refined petroleum

products, and demand for refined petroleum products tends to increase or decrease with the relative strength of the economy.

Customers

We provide storage and terminalling services for crude oil and refined petroleum products to many of the world’s largest producers of crude oil, integrated oil companies, chemical companies, oil traders and refiners. The largest customer of our storage segment is Valero Energy, which accounted for approximately 26%22% of the total revenues of the segment for the year ended December 31, 2008.2009. No other customer accounted for more than 10% of the revenues of the segment for this period. Our crude oil transshipment customers include an oil producer that leases and utilizes 5.0 million barrels of storage at St. Eustatius and a major international oil company that leases and utilizes 3.64.1 million barrels of storage at Point Tupper both of which haveunder a long-term contractscontract with us. In addition, two different internationalDuring 2009, an oil companies each leaseproducer leased and utilize more than 1.0utilized 5.0 million barrels of clean products storage at St. Eustatius and Point Tupper. Also,Eustatius. Beginning in Canada, a consortium consisting of major oil companies sends natural gas liquids via pipeline2010, we agreed to certain processing facilities on land leased from us. After processing, certain products are stored at the Point Tupper facility under a long-term contract.agreement to lease those 5.0 million barrels of storage to a national sponsored oil company, replacing the lease with the oil producer. In addition, our blending capabilities in our storage assets have attracted customers who have leased capacity primarily for blending purposes.

Competition and Business Considerations

Many major energy and chemical companies own extensive terminal storage facilities. Although such terminals often have the same capabilities as terminals owned by independent operators, they generally do not provide terminalling services to third parties. In many instances, major energy and chemical companies that own storage and terminalling facilities are also significant customers of independent terminal operators. Such companies typically have strong demand for terminals owned by independent operators when independent terminals have more cost-effective locations near key transportation links, such as deep-water ports. Major energy and chemical companies also need independent terminal storage when their owned storage facilities are inadequate, either because of size constraints, the nature of the stored material or specialized handling requirements.

Independent terminal owners generally compete on the basis of the location and versatility of terminals, service and price. A favorably located terminal will have access to various cost-effective transportation modes both to and from the terminal. Transportation modes typically include waterways, railroads, roadways and pipelines. Terminals located near deep-water port facilities are referred to as ‘‘deep-water“deep-water terminals,’’ and terminals without such facilities are referred to as ‘‘inland“inland terminals,’’ although some inland facilities located on or near navigable rivers are served by barges.

Terminal versatility is a function of the operator’s ability to offer complex handling requirements for diverse products. The services typically provided by the terminal include, among other things, the safe storage of the product at specified temperature, moisture and other conditions, as well as receipt at and delivery from the terminal, all of which must be in compliance with applicable environmental regulations. A terminal operator’s ability to obtain attractive pricing is often dependent on the quality, versatility and reputation of the facilities owned by the operator. Although many products require modest terminal modification, operators with versatile storage capabilities typically require less modification prior to usage, ultimately making the storage cost to the customer more attractive.

The main competition at our St. Eustatius and Point Tupper locations for crude oil handling and storage is from ‘‘lightering,’’“lightering,” which is the process by which liquid cargo is transferred from larger vessels to smaller vessels, usually while at sea. The price differential between lightering and terminalling is primarily driven by the charter rates for vessels of various sizes. Lightering generally takes significantly longer than discharging at a terminal. Depending on charter rates, the longer charter period associated with lightering is generally offset by various costs associated with terminalling, including storage costs, dock charges and spill response fees. However, terminalling is generally safer and reduces the risk of environmental damage associated with lightering, provides more flexibility in the scheduling of deliveries and allows our customers to deliver their products to multiple locations. Lightering in U.S. territorial waters creates a risk of liability for owners and shippers of oil under the U.S. Oil Pollution Act of 1990 and other state and federal legislation. In Canada, similar liability exists under the Canadian Shipping Act. Terminalling also provides customers with the ability to access value-added terminal services.

Our crude oil storage tanks are physically integrated with and serve refineries owned by Valero Energy. Additionally, we have entered into various agreements with Valero Energy governing the usage of these tanks. As a result, we believe that we will not face significant competition for our services provided to those refineries. Please read the disclosure contained

in Note 18 of Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for additional information regarding agreements with Valero Energy.

TRANSPORTATION

Our pipeline operations consist primarily of the transportation of refined petroleum products and crude oil. Our common carrier, refined product pipelines in Texas, Oklahoma, Colorado, New Mexico, Kansas, Nebraska, Iowa, South Dakota, North Dakota and Minnesota cover approximately 5,6795,605 miles. In addition, we own a 2,000 mile anhydrous ammonia

pipeline located in Louisiana, Arkansas, Missouri, Illinois, Indiana, Iowa and Nebraska. As of December 31, 2008,2009, we owned and operated:

 

2523 refined product pipelines with an aggregate length of 3,3393,255 miles that connect Valero Energy’s McKee, Three Rivers, Corpus Christi and Ardmore refineries to certain of NuStar Energy’s terminals, or to interconnections with third-party pipelines or terminals for further distribution, including a 25-mile hydrogen pipeline (collectively, the Central West System);

a 1,900-mile1,910-mile refined product pipeline originating in southern Kansas and terminating at Jamestown, North Dakota, with a western extension to North Platte, Nebraska and an eastern extension into Iowa (the East Pipeline);

a 440-mile refined product pipeline originating at Tesoro Corporation’s Mandan, North Dakota refinery (the Tesoro Mandan refinery) and terminating in Minneapolis, Minnesota (the North Pipeline); and

a 2,000-mile anhydrous ammonia pipeline originating at the Louisiana delta area that travels north through the midwestern United States forking east and west to terminate in Nebraska and Indiana (the Ammonia Pipeline).

As of December 31, 2008,2009, we also had an ownership interest in eleven crude oil pipelines in Texas, Oklahoma, Kansas, Colorado and Illinois with an aggregate length of 812 miles and crude oil storage facilities providing 1.9 million barrels of storage capacity in Texas, Oklahoma and Colorado that are located along the crude oil pipelines.

We charge tariffs on a per barrel basis for transporting refined products, crude oil and other feedstocks in our refined product and crude oil pipelines and on a per ton basis for transporting anhydrous ammonia in the Ammonia Pipeline.

Description of Pipelines

Central West System.The Central West System was constructed to support the refineries to which they are connected. These pipelines are physically integrated with and principally serve refineries owned by Valero Energy.

The refined products transported in these pipelines include gasoline, distillates (including diesel and jet fuel), natural gas liquids, (such as propane and butane),crude oil, blendstocks and other products produced primarily by Valero Energy’s McKee, Three Rivers, Corpus Christi and Ardmore refineries. These pipelines connect the Valero Energy refineries to key markets in Texas, New Mexico and Colorado. The Central West System transported approximately 164.9130.8 million barrels for the year ended December 31, 2008.2009.

The following table lists information about each of our refined product pipelines included in the Central West System:

 

Origin and Destination

  

Refinery

  

Length

  

Ownership

  

Capacity

  Refinery  Length  Ownership  Capacity
    (Miles)    (Barrels/Day)
     (Miles)     (Barrels/Day)

McKee to El Paso, TX

  McKee     408    67%    40,000  McKee    408      67%    40,000  

McKee to Colorado Springs, CO

  McKee     256  100%    38,000  McKee    256    100%    38,000  

Colorado Springs, CO to Airport

  McKee         2  100%    14,000  McKee    2    100%    14,000  

Colorado Springs to Denver, CO

  McKee     101  100%    32,000  McKee    101    100%    32,000  

McKee to Denver, CO

  McKee     321    30%      9,870  McKee    321    30%    9,870  

McKee to Amarillo, TX (6”) (a)

  McKee       49  100%    51,000  McKee    49    100%    51,000  

McKee to Amarillo, TX (8”) (a)

  McKee       49  100%    McKee    49    100%      

Amarillo to Abernathy, TX

  McKee     102    67%    11,733  McKee    102      67%    11,733  

Amarillo, TX to Albuquerque, NM (b)

  McKee     293    50%    17,150  McKee    293      50%    17,150  

Abernathy to Lubbock, TX

  McKee       19    46%      8,029  McKee    19      46%    8,029  

McKee to Skellytown, TX

  McKee       53  100%    52,000

McKee to Southlake, TX

  McKee     375  100%    27,300  McKee    375    100%    27,300  

Three Rivers to San Antonio, TX

  Three Rivers       81  100%    33,600  Three Rivers    81    100%    33,600  

Three Rivers to US/Mexico International Border near Laredo, TX

  Three Rivers     108  100%    32,000  Three Rivers    108    100%    32,000  

Corpus Christi to Three Rivers, TX

  Corpus Christi       68  100%    32,000  Corpus Christi    68    100%    32,000  

Three Rivers to Corpus Christi, TX

  Three Rivers       72  100%    15,000  Three Rivers    72    100%    15,000  

Three Rivers to Pettus to San Antonio, TX

  Three Rivers     103  100%    30,000  Three Rivers    103    100%    30,000  

Three Rivers to Pettus to Corpus Christi, TX (c)

  Three Rivers       87  100%    15,000  Three Rivers    87    100%    

N/A

  

Ardmore to Wynnewood, OK (d)

  Ardmore       31  100%    84,000

El Paso, TX to Kinder Morgan

  McKee       12    67%    65,600  McKee    12      67%    65,600  

Corpus Christi to Pasadena, TX

  Corpus Christi     208  100%  105,000  Corpus Christi    208    100%    105,000  

Corpus Christi to Brownsville, TX

  Corpus Christi     194  100%    45,000  Corpus Christi    194    100%    45,000  

US/Mexico International Border near Penitas, TX to Edinburg, TX

  N/A       33  100%    24,000  N/A    33    100%    24,000  

Clear Lake, TX to Texas City, TX

  N/A       25  100%          N/A  N/A    25    100%    N/A  

Other refined product pipeline (e)

  N/A     289    50%          N/A

Other refined product pipeline (d)

  N/A    289      50%    N/A  
                            

Total

    3,339    782,282      3,255        

631,282

  
                            

 

(a)

The capacity information disclosed above for the McKee to Amarillo, Texas 6-inch pipeline reflects both McKee to Amarillo, Texas pipelines on a combined basis.

(b)

Included in this segment are three refined product tanks with a total capacity of 114,000 barrels located at Tucamcari, New Mexico along the 10-inch Amarillo, Texas to Albequerque, New Mexico refined product pipeline.

(c)

The refined product pipeline from Three Rivers to Pettus to Corpus Christi, Texas is temporarily idled.

(d)

Included in this segment are two refined product storage tanks with a total capacity of 180,000 barrels located at Wynnewood, Oklahoma. Refined products may be stored and batched prior to shipment into a third party pipeline.

(e)

This category consists of the temporarily idled 6-inch Amarillo, Texas to Albuquerque, New Mexico refined product pipeline.

On June 15, 2009, we sold the Ardmore-Wynnewood pipeline in Oklahoma and the Trans-Texas pipeline for proceeds of $29.0 million.

East Pipeline.The East Pipeline covers 1,9001,910 miles and moves refined products and natural gas liquids north in pipelines ranging in sizediameter from 6 inches to 16 inches. The East Pipeline system also includes 21 product tanks with total storage capacity of approximately 1.2 million barrels at our two tanks farms at McPherson and El Dorado, Kansas. The East Pipeline transports refined petroleum products and natural gas liquids to our terminals along the system and to receiving pipeline connections in Kansas. Shippers on the East Pipeline obtain refined petroleum products from refineries in southeast Kansas connected to the East Pipeline orand through other pipelines directly connected to the pipeline system. The East Pipeline transported approximately 51.949.8 million barrels for the year ended December 31, 2008.2009.

North Pipeline.The North Pipeline is currently supplied by the Tesoro Mandan refinery and runs from west to east approximately 440 miles from its origin at the Tesoroin Mandan, refineryNorth Dakota to the Minneapolis, Minnesota area. The North Pipeline crosses our East Pipeline near Jamestown, North Dakota where the two pipelines are connected. While the North Pipeline is currently supplied primarily by the Tesoro Mandan

refinery, it is capable of delivering or receiving products to or from the East Pipeline. The North Pipeline transported approximately 16.4 million barrels forFor the year ended December 31, 2008.2009, the North Pipeline transported approximately 15.3 million barrels.

Pipeline RelatedPipeline-Related Terminals. The East and North Pipelines also include 21 truck-loading terminals through which refined petroleum products are delivered to storage tanks and then loaded into petroleum product transport trucks. Revenues earned at these terminals relate solely to the volumes transported on the pipeline. Separate fees are not charged for the use of these terminals. Instead, the terminalling fees are a portion of the transportation rate included in the pipeline tariff. As a result, these terminals are included in this segment instead of the storage segment.

The following table lists information about the tanks we own as of December 31, 2008 at each of our refined petroleum product terminals connected to the East or North Pipelines:

 

Location of Terminals  

Tank Capacity

  Number ofTanks  Related Pipeline
System
  (Barrels)        

Iowa:

              

LeMars

    103,000      8    East

Milford

    172,000      11    East

Rock Rapids

    223,000      5    East

Kansas:

              

Concordia

    79,000      6    East

Hutchinson

    114,000      5    East

Salina

    86,000      8    East

Minnesota:

              

Moorhead

    518,000      10    North

Sauk Centre

    116,000      7    North

Roseville

    479,000      10    North

Nebraska:

              

Columbus

    171,000      8    East

Geneva

    674,000      37    East

Norfolk

    182,000      15    East

North Platte

    247,000      23    East

Osceola

    79,000      7    East

North Dakota:

              

Jamestown (North)

    139,000      6    North

Jamestown (East)

    176,000      11    East

South Dakota:

              

Aberdeen

    181,000      12    East

Mitchell

    63,000      6    East

Sioux Falls

    381,000      12    East

Wolsey

    148,000      20    East

Yankton

    245,000      25    East
                

Total

    4,576,000      252    
                

Ammonia Pipeline.The 2,000 mile pipeline originates in the Louisiana delta area, where it has access to three marine terminals and three anhydrous ammonia plants on the Mississippi River. It runs north through Louisiana and Arkansas into Missouri, where at Hermann, Missouri, one branch splits and goes east into Illinois and Indiana, while the other branch continues north into Iowa and then turns west into Nebraska. The Ammonia Pipeline is connected to multiple third-party-owned terminals, which include industrial facility delivery locations. Product is supplied to the pipeline from anhydrous ammonia plants in Louisiana and imported product delivered through the marine terminals. Anhydrous ammonia is primarily used as agricultural fertilizer. It is also used as a feedstock to produce other nitrogen derivative

fertilizers and explosives. The Ammonia Pipeline transported approximately 1.51.2 million tons (or approximately 13.411.0 million barrels) for the year ended December 31, 2008.2009.

Crude Oil Pipelines. Our crude oil pipelines primarily transport crude oil and other feedstocks from various points in Texas, Oklahoma, Kansas and Colorado to Valero Energy’s McKee, Three Rivers and Ardmore refineries. Also, we can use our crude oil storage facilities in Texas, Oklahoma and Colorado, located along the crude oil pipelines, to store and batch crude oil prior to shipment in the crude oil pipelines. The crude pipelines transported approximately 128.4 million barrels for the year ended December 31, 2009.

The following table sets forth information about each of our crude oil pipelines:

 

Origin and Destination

  

Refinery

  

Length

  

Ownership

 

Capacity

    (Miles)   (Barrels/Day)

Cheyenne Wells, CO to McKee

  McKee    210    100%   17,500  

Dixon, TX to McKee

  McKee    44    100%   63,600  

Hooker, OK to Clawson, TX (a)

  McKee    41    50%   22,000  

Clawson, TX to McKee

  McKee    31    100%   36,000  

Wichita Falls, TX to McKee

  McKee    272    100%   110,000  

Corpus Christi, TX to Three Rivers

  Three Rivers    70    100%   120,000  

Ringgold, TX to Wasson, OK

  Ardmore    44    100%   90,000  

Healdton to Ringling, OK

  Ardmore    4    100%   52,000  

Wasson, OK to Ardmore (8”-10”) (b)

  Ardmore    24    100%   90,000  

Wasson, OK to Ardmore (8”)

  Ardmore    15    100%   40,000  

Patoka, IL to Wood River, IL

  Wood River    57      24%   60,600  
                 

Total

      812       701,700  
                 

 

(a)

We receive 50% of the tariff with respect to 100% of the barrels transported in the Hooker, Oklahoma to Clawson, Texas pipeline. Accordingly, the capacity is given with respect to 100% of the pipeline.

(b)

The Wasson, Oklahoma to Ardmore (8”- 10”) pipelines referred to above originate at Wasson as two pipelines but merge into one pipeline prior to reaching Ardmore.

The following table sets forth information about the crude oil storage facilities located along our crude oil pipelines:

 

Location

  

Refinery

  

Capacity

  

Number
of Tanks

  

Mode of

Receipt

  

Mode of

Delivery

   
    (Barrels)            

Dixon, TX

  McKee    240,000      3    pipeline  pipeline  

Ringgold, TX

  Ardmore    600,000      2    pipeline  pipeline  

Wichita Falls, TX

  McKee    660,000      4    pipeline  pipeline  

Wasson, OK

  Ardmore    225,000      2    pipeline  pipeline  

Clawson, TX

  McKee    65,000      2    pipeline  pipeline  

Other (a)

  McKee    67,000      3    pipeline  pipeline  
                      

Total

      1,857,000      16        
                      

 

(a)

This category includes crude oil tanks along the Cheyenne Wells, Colorado to McKee crude oil pipelines located at Carlton, Colorado, Sturgis, Oklahoma, and Stratford, Texas.

Other Pipelines.We also own three single-use pipelines, located near Umatilla, Oregon, Rawlings,Rawlins, Wyoming and Pasco, Washington, each of which supplies diesel fuel to a railroad fueling facility.

Pipeline Operations

Revenues for the refined product pipelines in the Central West System and the crude oil pipelines are based upon origin-to-destination throughput volumes traveling through our pipelines and the related tariffs. Revenues for the East Pipeline, the North Pipeline and the Ammonia Pipeline are based on how much and how far the product is shipped and the associated tariffs.

In general, a shipper on one of our refined petroleum product pipelines delivers products to the pipeline from refineries or third-party pipelines that connect to theour pipelines. Each shipper transporting product on a pipeline is required to supply us with a notice of shipment indicating sources of products and destinations. All shipments are tested or receive refinery certifications to ensure compliance with our specifications. Refined productWe charge our shippers are generally invoiced by us upon delivery for the Central West System and the North and Ammonia Pipelines and upon the product entering our East Pipeline. Tariffs fortariffs based on transportation are charged to shippers based upon transportation from

the origination point on the pipeline to the point of delivery. We invoice our refined product shippers upon delivery for our Central West System and our North and Ammonia Pipelines, and we invoice our shippers on our East Pipeline when their product enters the line.

Shippers on our crude oil pipelines deliver crude oil to the pipelines for transport to refineries that connect to the pipelines. The costs associated with the crude oil storage facilities located along the crude oil pipelines are considered in establishing the tariffs charged for transporting crude oil from the crude oil storage facilities to the refineries.

The refined product pipelines in the Central West System, the East Pipeline, the North Pipeline and the Ammonia Pipeline and the crude oil pipelines are subject to federal regulation by one or more of the following governmental agencies or laws: the Federal Energy Regulatory Commission (the FERC), the Surface Transportation Board (the STB), the Department of Transportation (DOT), the Environmental Protection Agency (EPA) and the Homeland Security Act. Additionally, the operations and integrity of the pipelines are subject to the respective state jurisdictions along the route of the systems.

The majority of our pipelines are common carrier and are subject to federal tariff regulation. In general, we are authorized by the FERC to adopt market-based rates. Common carrier activities are those for which transportation through our pipelines is available at published tariffs filed, in the case of interstate petroleum product shipments, with the FERC or, in the case of intrastate petroleum product shipments in Colorado, Kansas, North Dakota, Oklahoma and Texas, with the relevant state authority, to any shipper of refined petroleum products who requests such services and satisfies the conditions and specifications for transportation. The Ammonia Pipeline is subject to federal regulation by the STB and state regulation by Louisiana.

We use Supervisory Control and Data Acquisition remote supervisory control software programs to continuously monitor and control theour pipelines. The system monitors quantities of products injected in and delivered through the pipelines and automatically signals the appropriate personnel upon deviations from normal operations that require attention.

Demand for and Sources of Refined Products

The operations of our Central West System and the East and North Pipelines depend in large part on the level of demand for refined products in the markets served by the pipelines and the ability and willingness of refiners and marketers having access to the pipelines to supply such demand by deliveries through the pipelines.

The majority of the refined products delivered through the pipelines in the Central West System are gasoline and diesel fuel that originate at refineries owned by Valero Energy. Demand for these products fluctuates as prices for these products fluctuate. Prices fluctuate for a variety of reasons including the overall balance in supply and demand, which is affected by general economic conditions and affects refinery utilization rates, among other factors. Prices for gasoline and diesel fuel tend to increase in the warm weather months when people tend to drive automobiles more often and further.further distances.

The majority of the refined products delivered through the North Pipeline are delivered to the Minneapolis, Minnesota metropolitan area and consist of gasoline and diesel fuel. Demand for those products fluctuates based on general economic conditions and with changes in the weather as more people drive during the warmer months.

Much of the refined products and natural gas liquids delivered through the East Pipeline and volumes on the North Pipeline that are not delivered to Minneapolis are ultimately used as fuel for railroads, ethanol denaturant or in agricultural operations, including fuel for farm equipment, irrigation systems, trucks used for transporting crops and crop-drying facilities. Demand for refined products for agricultural use, and the relative mix of products required, is affected by weather conditions in the markets served by the East and North Pipelines. The agricultural sector is also affected by government agricultural policies and crop prices. Although periods of drought suppress agricultural demand for some refined products, particularly those used for fueling farm equipment, the demand for fuel for irrigation systems often increases during such times. The mix of refined products delivered for agricultural use varies seasonally, with gasoline demand peaking in early summer, diesel fuel demand peaking in late summer and propane demand higher in the fall. In addition, weather conditions in the areas served by the East Pipeline affect the mix of the refined products delivered through the East Pipeline, although historically any overall impact on the total volumes shipped has not been significant.

Our refined product pipelines are also dependent upon adequate levels of production of refined products by refineries connected to the pipelines, directly or through connecting pipelines. The refineries are, in turn, dependent upon adequate

supplies of suitable grades of crude oil. The pipelines in the Central West System and our crude oil pipelines are connected to refineries owned by Valero Energy, and certain pipelines are subject to long-term throughput agreements with Valero Energy. Valero Energy’sEnergy refineries connected directly to our pipelines obtain crude oil from a variety of foreign and domestic sources. If operations at one of these refineries were discontinued or significantly reduced, it could have a material adverse effect on our operations, although we would endeavor to minimize the impact by seeking alternative customers for those pipelines.

The North Pipeline is heavily dependent on the TesoroTesoro’s Mandan, North Dakota refinery, which primarily runs North Dakota crude oil (although it has the ability to runprocess other crude oils). If operations at the Tesoro Mandan refinery were interrupted, it could have a material effect on our operations. Other than the Valero Energy refineries described above and the Tesoro Mandan refinery, if operations at any one refinery were discontinued, we believe (assuming unchanged demand for refined products in markets served by the refined product pipelines) that the effects thereof would be short-term in nature and our business would not be materially adversely affected over the long term because such discontinued production could be replaced by other refineries or other sources.

The refineries connected directly to the East Pipeline obtain crude oil from producing fields located primarily in Kansas, Oklahoma and Texas, and, to a much lesser extent, from other domestic or foreign sources. In addition, refineries in Kansas, Oklahoma and Texas are also connected to the East Pipeline by third party pipelines. These refineries obtain their supplies of crude oil from a variety of sources. The majority of the refined products transported through the East Pipeline are produced at three refineries located at McPherson and El Dorado, Kansas and Ponca City, Oklahoma, which are operated by the National Cooperative Refining Association (NCRA), Frontier Oil Corporation and ConocoPhillips Company, respectively. The NCRA and Frontier RefiningOil Corporation refineries are connected directly to the East Pipeline. The East Pipeline also has access to Gulf Coast supplies of products through third party connecting pipelines that receive products originating on the Gulf Coast.

Demand for and Sources of Anhydrous Ammonia

The Ammonia Pipeline is one of two major anhydrous ammonia pipelines in the United States and the only one capable of receiving foreign production directly into the system and transporting anhydrous ammonia into the nation’s corn belt.

Our Ammonia Pipeline operations depend on overall nitrogen fertilizer use, management practice,practices, the price of natural gas, which is the primary component of anhydrous ammonia, and the level of demand for direct application of anhydrous ammonia as a fertilizer for crop production (Direct Application). Demand for Direct Application is dependent on the weather, as Direct Application is not effective if the ground is too wet or too dry.

Corn producers have fertilizer alternatives to anhydrous ammonia, such as liquid or dry nitrogen fertilizers. Liquid and dry nitrogen fertilizers are both less sensitive to weather conditions during application but are generally more costly than anhydrous ammonia. However,In addition, anhydrous ammonia has the highest nitrogen content of any nitrogen-derivative fertilizer.

Customers

The largest customer of our transportation segment was Valero Energy, which accounted for approximately 51%49% of the total segment revenues for the year ended December 31, 2008.2009. In addition to Valero Energy, we had a total of approximately 6570 shippers for the year ended December 31, 2008,2009, including integrated oil companies, refining companies, farm cooperatives, railroads and a railroad.others. No other customer accounted for greater than 11%10% of the total revenues of transportation segment for the year ended December 31, 2008.

Competition and Business Considerations

Because pipelines are generally the lowest-cost method for intermediate and long-haul movement of refined petroleum products, our more significant competitors are common carrier and proprietary pipelines owned and operated by major integrated and large independent oil companies and other companies in the areas where we deliver products. Competition between common carrier pipelines is based primarily on transportation charges, quality of customer service and proximity to end users. We believe high capital costs, tariff regulation, environmental considerations and problems in acquiring rights-of-way make it unlikely that other competing pipeline systems comparable in size and scope to our pipelines will be built in the near future, as long as our pipelines have available capacity to satisfy demand and our tariffs remain at economically reasonable levels.

The costs associated with transporting products from a loading terminal to end users limit the geographic size of the market that can be served economically by any terminal. Transportation to end users from our loading terminals is conducted primarily by trucking operations of unrelated third parties. Trucks may competitively deliver products in some of the areas served by our pipelines. However, trucking costs render that mode of transportation uncompetitive for longer hauls or larger volumes. We do not believe that trucks are, or will be, effective competition to our long-haul volumes over the long-term.

OurMost of our refined product pipelines within the Central West System and our crude oil pipelines are physically integrated with and principally serve refineries owned by Valero Energy. Certain pipelines are subject to long-term throughput agreements with Valero Energy. As the pipelines are physically integrated with Valero Energy’s refineries, we believe that we will not face significant competition for transportation services provided to the Valero Energy refineries we serve. Please read the disclosure contained in Note 18 of Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for additional information on our agreements with Valero Energy.

The East and North Pipelines compete with an independent common carrier pipeline system owned by Magellan Midstream Partners, L.P. (Magellan) that operates approximately 100 miles east of and parallel to the East Pipeline and in close proximity to the North Pipeline. The Magellan system is a more extensive system than the East and North Pipelines. Competition with Magellan is based primarily on transportation charges, quality of customer service and proximity to end users. In addition, refined product pricing at either the origin or terminal point on a pipeline may outweigh transportation costs. Certain of the East Pipeline’s and the North Pipeline’s delivery terminals are in direct competition with Magellan’s terminals.

Competitors of the Ammonia Pipeline include another anhydrous ammonia pipeline that originates in Oklahoma and Texas and terminates in Iowa.Minnesota. The competing pipeline has the same Direct Application demand and weather issues as the Ammonia Pipeline but is restricted to domestically produced anhydrous ammonia. Midwest production facilities, nitrogen fertilizer substitutes and barge and railroad transportation represent other forms of direct competition to the pipeline under certain market conditions.

ASPHALT AND FUELS MARKETING

Our asphalt and fuels marketing segment includes our asphalt refining operations and our fuels marketing operations. We refine crude oil to produce asphalt and certain other refined products from our asphalt operations. Additionally, we purchase gasoline and other refined petroleum products for resale. The results of operations for the asphalt and fuels marketing segment depend largely on the margin between our cost and the sales price of the products we market. Therefore, the results of operations for this segment are more sensitive to changes in commodity prices compared to the operations of the storage and transportation segments.

Asphalt Refining and Marketing Operations

Our asphalt refining operations acquired on March 20, 2008 diversified our customer base, expanded our geographic presence and complemented our preexisting asphalt marketing and terminals business. The following table lists information about our asphalt refineries and related terminals as of December 31, 2008:2009. The tank capacity includes storage for asphalt, crude oil and other feedstocks.

 

Facility

  

Production

Capacity

  

Tank Capacity

  

Number of

Tanks

  

Production

Capacity

  Tank Capacity  Number of
Tanks
  (Barrels Per Day)  (Barrels)     (Barrels Per Day)  (Barrels)      

Paulsboro, NJ

    74,000      3,640,000      24  

Savannah, GA

  30,000  1,195,000  21    30,000      1,359,000      25  

Paulsboro, NJ

  74,000  3,523,000  21
                              

Total

  104,000  4,718,000  42    104,000      4,999,000      49  
                              

Paulsboro Refinery.The Paulsboro refinery is located in Paulsboro, New Jersey on the Delaware River. The refinery consists of two petroleum refining units, a liquid storage terminal for petroleum and chemical products, three marine docks, a polymer-modified asphalt production facility and a testing laboratory. The Paulsboro refinery supplies various asphalt grades and intermediate products by ship, barge, railcar and tanker trucks to a network of 11 asphalt terminals in the northeastern United States. These asphalt terminals provide us with an aggregate storage capacity of 3.8 million barrels and are either leased from third parties or owned by us. The Paulsboro refinery’s location on the Delaware River allows for direct access of receipts and shipments.

The following table lists the throughputs and percentages of yields for each refinery for the period from March 20, 2008, the date of acquisition, through December 31, 2008:

   

Volumes

  

Percentage

   (barrels per day)   

Savannah:

    

Crude oil throughput

  25,092  

Yields:

    

Asphalt

  18,643  74%

Naphtha

  952  4%

Light marine gas oil

  5,466  22%

Paulsboro:

    

Crude oil throughput

  55,973  

Yields:

    

Asphalt

  38,066  68%

Naphtha

  1,390  3%

Marine diesel oil

  9,447  17%

Vacuum gas oil

  6,723  12%

Savannah Refinery.The Savannah refinery is located in Savannah, Georgia adjacent to the Savannah River and is the only asphalt producer on the United States southeastern seaboard. The refinery includes two atmospheric towers, a tank farm, a marine dock, a polymer modified asphalt production facility, a testing laboratory and processing areas. The Savannah refinery supplies various asphalt grades by truck, rail and marine vessel to a network of eight11 asphalt terminals in the southeastern United States. These asphalt terminals provide us with an aggregate storage capacity of 1.9 million barrels and are either leased from third parties or owned by us. The Savannah refinery’s location on the Savannah River allows for direct access of receipts and shipments.

Paulsboro Refinery.    The Paulsboro refinery is located in Paulsboro, New Jersey onWe have access to an aggregate asphalt storage capacity of almost 8.0 million barrels, which includes the Delaware River. The refinery consists of two petroleum refining units, a liquid storage terminal for petroleum and chemical products, three marine docks, a polymer modified asphalt production facility and a testing laboratory. The Paulsboro refinery supplies various asphalt grades and intermediate products by ship, barge, railcar and tanker trucks to a network of nine asphalt terminals inassociated with the northeastern United States. TheseSavannah and Paulsboro refineries combined with seven other asphalt terminals are either leased from third parties or owned by us. terminals.

The Paulsboro refinery’s location onfollowing table lists the Delaware River allowsthroughputs and percentages of yields for direct access of receipts and shipments.each refinery for the year ended December 31, 2009:

   

Volumes

 

Percentage

  (barrels per day) 

Paulsboro:

   

Crude oil throughput

  45,025 

Yields:

   

Asphalt

  27,103 61%

Naphtha

    1,267   3%

Marine diesel oil

    6,786 15%

Vacuum gas oil

    3,651   8%

HS fuel oil

    5,982 13%

Savannah:

   

Crude oil throughput

  17,991 

Yields:

   

Asphalt

  13,362 75%

Naphtha

       591   3%

Light marine gas oil

     3,995 22%

Customers.We produce several grades of asphalt products for various applications. The asphalt we produce is for hot mix paving, which is used in road construction, roofing shingles for housing, asphalt emulsions and asphalt cutbacks used for street maintenance, as well as polymer-modified asphalt, which is a premium asphalt cement used for roads with heavy traffic in harsh weather conditions. The majority of our asphalt customers are road and bridge construction companies who operate asphalt hot mix plants that combine rock aggregate with asphalt to make road pavements. Approximately 50% of theseOur customers serve the private commercial sector by building residential roads, parking lots, asphalt paths and courts. The other half servescourts as well as the public sector by building highways and transportation infrastructure for the various state Departments of Transportation. We also have a small number of customers who manufacture residential asphalt roofing shingles and building materials.

Crude Supply. Simultaneously with the acquisition of the East Coast Asphalt Operations,our asphalt operations, Petróleos de Venezuela S. A. (PDVSA), the national oil company of Venezuela, agreed to supply us with Boscan and Bachaquero BCF-13 crude oil as feedstocks for our refineries. Our cost of crude oil purchased under the supply agreement fluctuates based upon a market-based pricing formula using published market indices, subject to adjustment, based on the price of Mexican Maya crude. Our refineries are optimized to process Boscan and Bachaquero BCF-13 crude oil and doing so typically results in the best economic return. However, the refineries can also process alternative asphaltic crudes and other feedstocks.

Competition and Business Considerations. The asphalt industry is highly fragmented and regional in nature. Our competitors range in size from major oil companies and independent refiners to small family-owned businesses. It is considered a niche business with few integrated, asphalt-focused refiners that have production, logistics and wholesale and marketing capabilities. The top asphalt producers in the U.S. are refiners that produce asphalt as a by-product.

Over the long term, we expect to benefit from higher asphalt margins because many U.S. refiners are planning new coker projects or coker expansions, which should reduce the overall supply of asphalt. Cokers break down the heaviest fractions of crude oil into lighter, higher value products and elemental carbon, or coke. As a result, asphalts and heavy fuel oils are

reprocessed into transportation fuels like gasoline and diesel. As the supply of asphalt decreases, asphalt margins shouldare expected to increase.

Fuels Marketing Operations

Our fuels marketing operations provide us the opportunity to generate additional gross margin while complementing the activities of our storage and transportation segments. Specifically, we purchase gasoline, distillates and refinery feedstocks to take advantage of arbitrage opportunities and contango markets (when the price for future deliveries exceeds current prices). During a contango market, we can utilize storage at strategically located terminals, including our own terminals, to deliver products at favorable prices. Additionally, we may take advantage of geographic arbitrage opportunities by utilizing transportation and storage assets, including our own terminals and pipelines, to deliver products from one geographic region to another with more favorable pricing. We also purchase gasoline and distillates in spot markets from refiners and traders, andwhich we then offer for sale to wholesale customers through approximately 50 terminals approximately 45% of which are owned by NuStar Energy.us or third-parties. The remaining 55% is sold through third-party-leased facilities. Thegross margin we generate reflects the wholesale uplift above spot market prices, less terminalingterminalling and transportation fees.

As part of these operations, we may utilize storage space in certain of our refined products terminals and terminals operated by third parties. We may also obtain transportation services from our refined products pipelines and other third partythird-party providers. Rates charged by our storage segment to the asphalt and fuels marketing segment are consistent with rates charged to third parties. Because the majority of our pipelines are common carrier pipelines, the tariffs charged to the asphalt and fuels marketing segment from the transportation segment are based upon the published tariff applicable to all shippers.

In addition, we sell bunker fuel from our terminal locations at St. Eustatius and Point Tupper where we also store bunker fuel for third parties. The strategic location of these two facilities and their storage capabilities provide us with a reliable supply of product and the ability to capture incremental sales margin. Also, the St. Eustatius terminal facility has six mooring locations that can supply bunkers to vessels up to 520,000 deadweight tons, and the Point Tupper facility has two mooring locations that can supply bunkers to vessels up to 400,000 deadweight tons. In 2009, we began limited bunkering operations at certain of our U.S. terminals.

Since the operations of our asphalt and fuels marketing segment expose us to commodity price risk, we sometimes enter into derivative instruments to mitigate the effect of commodity price fluctuations on our operations. The derivative instruments we use consist primarily of futures contracts and swaps traded on the NYMEX for the purposes of hedging the outright price risk of our physical inventory.

Customers. FuelFuels marketing customers include major integrated refiners and trading companies, as well as various wholesale suppliers, unbranded retailers and large high volume retailers. Customers for our bunker fuel sales are ship owners, including cruise line companies.

Competition and Business Considerations. Our Fuels Marketingfuels marketing operations have numerous competitors, including large integrated refiners, marketing affiliates of other partnerships in our industry, as well as various international and domestic trading companies. In the sale of bunker fuel, we compete with ports offering bunker fuels to which, or from which, each vessel travels or that are along the route of travel of the vessel. We also compete with bunker fuel delivery locations around the world. In the Western Hemisphere, alternative bunker fuel locations include ports on the U.S. East Coast and Gulf Coast and in Panama, Puerto Rico, the Bahamas, Aruba, Curacao and Halifax, Nova Scotia.

EMPLOYEES

Our operations are managed by NuStar GP, LLC. As of December 31, 2008,2009, NuStar GP, LLC had 1,3401,379 employees performing services for our U.S. operations. Certain of our wholly owned subsidiaries had 344374 employees performing services for our international operations. We believe that NuStar GP, LLC and our subsidiaries each have satisfactory relationships with their employees.

RATE REGULATION

Several of our petroleum pipelines are interstate common carrier pipelines, which are subject to regulation by the FERC under the Interstate Commerce Act (ICA) and the Energy Policy Act of 1992 (the EP Act). The ICA and its implementing regulations give the FERC authority to regulate the rates charged for service on interstate common carrier pipelines and generally require the rates and practices of interstate oil pipelines to be just, reasonable and nondiscriminatory. The ICA also requires tariffs that set forth the rates a common carrier pipeline charges for providing transportation services on its interstate common carrier liquids pipelines, as well as the rules and regulations governing these services, to be maintained on file with the FERC. The EP Act deemed certain rates in effect prior to its passage to be just and reasonable and limited the circumstances under which a complaint can be made against such ‘‘grandfathered’’“grandfathered” rates. The EP Act and its implementing regulations also allow interstate common carrier oil pipelines to annually index their rates up to a prescribed ceiling level. In addition, the FERC retains cost-of-service ratemaking, market-based rates and settlement rates as alternatives to the indexing approach.

The Ammonia Pipeline is subject to regulation by the STB under the current version of the ICA. The ICA and its implementing regulations give the STB authority to regulate the rates we charge for service on the Ammonia Pipeline and generally require that our rates and practices be just, reasonable and nondiscriminatory.

Additionally, the rates and practices for our intrastate common carrier pipelines are subject to regulation by state commissions in Colorado, Kansas, Louisiana, North Dakota and Texas. Although the applicable state statutes and regulations vary, they generally require that intrastate pipelines publish tariffs setting forth all rates, rules and regulations applying to intrastate service, and generally require that pipeline rates and practices be just, reasonable and nondiscriminatory.

Shippers may challenge tariff rates rules and practicesregulations on our pipelines. There are no pending challenges or complaints regarding our tariff rates. We dotariffs. It is not currently believe that it is likely that there will be a challenge to the tariffs on our ammonia, petroleum products or crude oil pipelines by a current shipper that would materially affect our revenues or cash flows. However, the FERC, the STB or a state regulatory commission could investigate our tariffs on their own motion or upon a complaint filed by a third party. Also, since our pipelines are common carrier pipelines, we may be required to accept new shippers who wish to transport in our pipelines and who could potentially decide to challenge our tariffs.

ENVIRONMENTAL AND SAFETY REGULATION

Our operations are subject to extensive federal, state and local environmental laws and regulations, including those relating to the discharge of materials into the environment, waste management and pollution prevention measures. Our operations are also subject to extensive federal and state health and safety laws and regulations, including those relating to pipeline safety. The principal environmental and safety risks associated with our operations relate to unauthorized emissions into the air, unauthorized releases into soil, surface water or groundwater and personal injury and property damage. Compliance with these environmental and safety laws, regulations and permits increases our capital expenditures and our overall cost of business, and violations of these laws, regulations and/or permits can result in significant civil and criminal liabilities, injunctions or other penalties.

We have adopted policies, practices and procedures in the areas of pollution control, pipeline integrity, operator qualifications, public relations and education, product safety, process safety management, occupational health and the handling, storage, use and disposal of hazardous materials that are designed to prevent material environmental or other damage, to ensure the safety of our pipelines, our employees, the public and the environment and to limit the financial liability that could result from such events. Future governmental action and regulatory initiatives could result in changes to expected operating permits and procedures, additional remedial actions or increased capital expenditures and operating costs that cannot be assessed with certainty at this time. In addition, contamination resulting from spills of crude oil and

refined products occurs within the industry. Risks of additional costs and liabilities are inherent within the industry, and there can be no assurances that significant costs and liabilities will not be incurred in the future.

Capital Expenditures Attributable to Compliance with Environmental Regulations. In 2008,2009, our capital expenditures attributable to compliance with environmental regulations were $4.8$9.1 million, and are currently estimated to be approximately $12.0 million for 2009 and approximately $3.5 million for 2010. The estimates for 2009 and 2010 dodoes not include amounts related to capital investments at our facilities that management has deemed to be strategic investments rather than expenditures relating to environmental regulatory compliance.

RENEWABLE ENERGY AND ALTERNATIVE FUEL MANDATES

Several federal and state programs require the purchase and use of renewable energy and alternative fuels, such as battery-powered engines, biodiesel, wind energy, and solar energy. These mandates could impact the demand for refined petroleum products. In December 2007, Congress enacted the Energy Independence and Security Act of 2007, which, among things, mandated annually increasing levels for the use of renewable fuels such as ethanol, commencing in 2008 and escalating for 15 years, as well as increasing energy efficiency goals, including higher fuel economy standards for motor vehicles, among other steps. These statutory mandates may have the impact over time of offsettingoffset projected increases or reducingreduce the demand for refined petroleum products, particularly gasoline, in certain markets. The increased production and use of biofuels may also create opportunities for additional pipeline transportation and additional blending opportunities within the terminals division, although that potential cannot be quantified at present. Other legislative changes may similarly alter the expected demand and supply projections for refined petroleum products in ways that cannot be predicted.

WATER

The Federal Water Pollution Control Act of 1972, as amended, also known as the Clean Water Act, and analogous or more stringent state statutes impose restrictions and strict controls regarding the discharge of pollutants into state waters or waters of the United States. The discharge of pollutants into state waters or waters of the United States is prohibited, except in accordance with the terms of a permit issued by applicable federal or state authorities. The Oil Pollution Act, enacted in 1990, amends provisions of the Clean Water Act as they pertain to prevention and response to oil spills. Spill prevention control and countermeasure requirements of the Clean Water Act and some state laws require the use of dikes and similar structures to help prevent contamination of state waters or waters of the United States in the event of an overflow or release. Violations of any of these statutes and the related regulations could result in significant costs and liabilities.

AIR EMISSIONS

Our operations are subject to the Federal Clean Air Act, as amended, and analogous or more stringent state and local statutes. These laws and regulations regulate emissions of air pollutants from various industrial sources, including some of our operations, and also impose various monitoring and reporting requirements. Such laws and regulations may require a facility to obtain pre-approval for the construction or modification of certain projects or facilities expected to produce air emissions or result in the increase of existing air emissions, and obtain and strictly comply with the provisions of any air permits. It is possible that these statutes and the related regulations may be revised to be more restrictive in the future, necessitating additional capital expense to ensure our operations are in compliance. We are unable to estimate the effect on our financial condition or results of operations or the amount and timing of such required expenditures.

Congress is currently considering proposed legislation directed at reducing “greenhouse gas emissions.” The state of California adopted the California Global Warming Solutions Act of 2006, which requires a 25% reduction in greenhouse gas emissions by 2020. This legislation requires the California Air Resources Board to adopt regulations by 2012 that limit emissions until an overall reduction of 25% from all emission sources in California is to be achieved by 2020. Recently, the California Air Resources Board announced its intention to have a proposed draft of its greenhouse gas mandatory reporting regulation by mid-2009. New Jersey has adopted legislation addressing greenhouse gas emissions from various sources, primarily power plants. The oil and natural gas industry is a direct source of greenhouse gas emissions and future restrictions on such emissions could have an impact on our future operations. It is not possible at this time to estimate accurately how future laws or regulations to address greenhouse gas emissions would affect our business.

SOLID WASTE

We generate non-hazardous and minimal quantities of hazardous solid wastes that are subject to the requirements of the federal Resource Conservation and Recovery Act (RCRA) and analogous or more stringent state statutes. We are not currently required to comply with a substantial portion of RCRA requirements because our operations generate minimal quantities of hazardous wastes. However, it is possible that additional wastes, which could include wastes currently generated during operations, will also be designated as “hazardous wastes.” Hazardous wastes are subject to more rigorous and costly disposal requirements than are non-hazardous wastes.

HAZARDOUS SUBSTANCES

The Comprehensive Environmental Response, Compensation and Liability Act, referred to as CERCLA and also known as Superfund, and analogous or more stringent state laws, imposes liability, without regard to fault or the legality of the original act, on some classes of persons that contributed to the release of a “hazardous substance” into the environment. These persons include the owner or operator of the site and entities that disposed or arranged for the disposal of the hazardous substances found at the site. CERCLA also authorizes the Environmental Protection Agency (EPA)EPA and, in some instances, third parties to act in response to threats to the public health or the environment and to seek recovery from the responsible classes of persons for the costs that they incur. In the course of our ordinary operations, we may generate waste that falls within CERCLA’s definition of a “hazardous substance.”

We currently own or lease, and have in the past owned or leased, properties where hydrocarbons are being or have been handled. Although we have utilized operating and disposal practices that were standard in the industry at the time, hydrocarbons or other wastes may have been disposed of or released on or under the properties owned or leased by us or on or under other locations where these wastes have been taken for disposal. In addition, many of these properties have been operated by third parties whose treatment and disposal or release of hydrocarbons or other wastes was not under our control. These properties and wastes disposed thereon may be subject to CERCLA, RCRA and analogous state laws. Under these laws, we could be required to remove or remediate previously disposed wastes (including wastes disposed of or released by prior owners or operators), to clean up contaminated property (including contaminated groundwater) or to perform remedial operations to prevent future contamination. In addition, we may be exposed to joint and several liability

under CERCLA for all or part of the costs required to clean up sites at which hazardous substances may have been disposed of or released into the environment.

Remediation of subsurface contamination is in process at many of our facilities. Based on current investigative and remedial activities, we believe that the cost of these activities will not materially affect our financial condition or results of operations. Such costs, however, are often unpredictable and, therefore, there can be no assurances that the future costs will not become material.

PIPELINE INTEGRITY AND SAFETY

Our pipelines are subject to extensive federal and state laws and regulations governing pipeline integrity and safety. The federal Pipeline Safety Improvement Act of 2002 and its implementing regulations (collectively, PSIA) generally require pipeline operators to maintain qualification programs for key pipeline operating personnel, to review and update their existing pipeline safety public education programs, to provide information for the National Pipeline Mapping System, to maintain spill response plans, to conduct spill response training and to implement integrity management programs for pipelines that could affect high consequence areas (i.e., areas with concentrated populations, navigable waterways and other unusually sensitive areas). While compliance with PSIA and analogous or more stringent state laws may affect our capital expenditures and operating expenses, we believe that the cost of such compliance will not materially affect our competitive position or have a material effect on our financial condition or results of operations.

The Pipeline Inspection, Protection, Enforcement, and Safety Act of 2006 (PIPES Act) became effective in December 2006. The PIPES Act included requirements to strengthen damage prevention measures designed to protect pipelines from excavation damage, eliminate an exemption from regulation for certain low-stress hazardous liquid pipelines, and require pipeline operators to manage human factors in pipeline control centers, including controller fatigue. While the PIPES Act imposed additional operating requirements on pipeline operators, we do not believe that the costs of compliance with the Pipes Act will have a material effect on our financial condition or results of operations.

RISK FACTORS

RISKS RELATED TO OUR BUSINESS

We may not be able to generate sufficient cash from operations to enable us to pay distributions at current levels to our unitholders every quarter.

The amount of cash that we can distribute to our unitholders each quarter principally depends upon the amount of cash we generate from our operations, which will fluctuate from quarter to quarter based on, among other things:

 

the amount of crude oil, refined product and anhydrous ammoniathroughput volumes transported in our pipelines;

lease renewals or throughput volumes in our terminals and storage facilities;

tariff rates and fees we charge and the returns we realize for our services;

the results of our marketing, trading and hedging activities, which fluctuate depending upon the relationship between refined product prices and prices of crude oil and other feedstocks;

demand for crude oil, refined products and anhydrous ammonia;

the effect of worldwide energy conservation measures;

our operating costs;

weather conditions;

domestic and foreign governmental regulations and taxes; and

prevailing economic conditions.

In addition, the amount of cash that we will have available for distribution will depend on other factors, including:

 

our debt service requirements and restrictions on distributions contained in our current or future debt agreements;

the sources of cash used to fund our acquisitions;

our capital expenditures;

fluctuations in our working capital needs;

issuances of debt and equity securities; and

adjustments in cash reserves made by our general partner, in its discretion.

Because of these factors, we may not have sufficient available cash each quarter to continue paying distributions at their current level or at all. Furthermore, cash distributions to our unitholders depend primarily upon cash flow, including cash flow from financial reserves and working capital borrowings, and not solely on profitability, which is affected by non-cash items. Therefore, we may make cash distributions during periods when we record net losses and may not make cash distributions during periods when we record net income.

Reduced demand for refined products including asphalt, or anhydrous ammonia could affect our results of operations and ability to make distributions to our unitholders.

Any sustained decrease in demand for refined products including asphalt, in the markets served by our pipelines, terminals or refineries could result in a significant reduction in throughputs in our pipelines, storage in our terminals or sales of asphalt and other refined products, which would reduce our cash flow and our ability to make distributions to our unitholders. Factors that could lead to a decrease in market demand include:

 

a recession or other adverse economic condition that results in lower spending by consumers on gasoline, diesel and travel;

higher fuel taxes or other governmental or regulatory actions that increase, directly or indirectly, the cost of gasoline;

a decrease in spending by federal or state governments on construction projects, including road paving and maintenance;

an increase in automotive engine fuel economy, whether as a result of a shift by consumers to more fuel-efficient vehicles or technological advances by manufacturers;

an increase in the market price of crude oil that leads to higher refined product prices, including asphalt prices, which may reduce demand for refined products and drive demand for alternative products. Market prices for crude oil and refined products, including asphalt, are subject to wide fluctuation in response to changes in global and regional supply that are beyond our control, and increases in the price of crude oil may result in a lower demand for refined products, including asphalt;

a decrease in corn acres planted, which may reduce demand for anhydrous ammonia; and

the increased use of alternative fuel sources, such as battery-powered engines. Several state and federal initiatives mandate this increased use. For example, the Energy Policy Act of 1992 requires 75% of new vehicles

purchased by federal agencies since 1999, 75% of all new vehicles purchased by state governments since 2000, and 70% of all new vehicles purchased for private fleets in 2006 and thereafter to use alternative fuels.

A decrease in lease renewals or throughputs in our assets would cause our revenues to decline and could adversely affect our ability to make cash distributions to our unitholders.

A decrease in lease renewals or throughputs in our assets would cause our revenues to decline and could adversely affect our ability to make cash distributions to our unitholders. ASuch a decrease in throughputs could result from either a customer’s failure to renew a lease or a temporary or permanent decline in the amount of crude oil transported to and stored at or refined products stored at and transported from the refineries we serve and own. Factors that could result in such a decline include:

a material decrease in the supply of crude oil;

a material decrease in demand for refined products in the markets served by our pipelines, terminals and refineries;

scheduled refinery turnarounds or unscheduled refinery maintenance;

operational problems or catastrophic events at a refinery;

environmental proceedings or other litigation that compel the cessation of all or a portion of the operations at a refinery;

a decision by our current customers to redirect refined products transported in our pipelines to markets not served by our pipelines or to transport crude oil or refined products by means other than our pipelines;

increasingly stringent environmental regulations; or

a decision by our current customers to sell one or more of the refineries we serve to a purchaser that elects not to use our pipelines and terminals.

We may not be able to effectively integrate the East Coast Asphalt Operations.

We continue to face certain challenges as we work to integrate theOur asphalt operations into our business. In particular, the acquisition of the East Coast Asphalt Operations, by adding two refineries expanded our operations, geographic scope and the types of businesses in which we engage, thereby presenting us with significant challenges as we work to manage the increase in scale resulting from the acquisition. Further, the asphalt operations may not perform in accordance with our expectations, and our expectations with regards to integration and synergies may not be fully realized. Our failure to realize the anticipated benefits of the acquisition, could adversely affect our operating and financial results.

The East Coast Asphalt Operations are dependent upon a steady supply of crude oil from PDVSA, the national oil company of Venezuela, and decisions of the Organization of Petroleum Exporting Countries (OPEC) to decrease production of crude oil, as well as the Venezuelan economic and political environment, may disrupt our supply of crude oil.

The terms of the acquisition of the East Coast Asphalt Operations include commitments, over a minimum seven-year period,We have an agreement with PDVSA, pursuant to which PDVSA agrees to sell and we agree to purchase from PDVSA an annual average of 75,000 barrels per day of crude oil and provide us with a right of first offer to purchase up to 4,000,000 barrels of paving grade asphalt and 4,750,000 barrels of roofing flux asphalt each year for marketing and sale.oil. In December 2008, OPEC, which includes Venezuela, agreed to decrease production by 2.2 million barrels of crude oil per day and we received notice from PDVSA that it would cutreduced contractual deliveries by two 300,000 barrel Boscán cargoes in February 2009 and twoone in March. To date, theseMarch 2009. These production decreases have not had a material impact on our financial results. Additional OPEC cuts, coupled with Venezuela’s recent political, economic and social turmoil could have a severe impact on PDVSA’s production or delivery of crude oil. In the event PDVSA further reduces its production or delivery of Boscán or Bachaquero BCF-13, the crude oil for which our refineries are currently optimized, we will be forced to replace all or a portion of the crude oil we would normally have purchased under our PDVSA crude oil supply contract with purchases of crude oil on the spot market, potentially at a price less favorable than we would have obtained under the PDVSA crude oil supply contract. While we have found satisfactory replacement crudes for the February and March 2009 cuts, it is possible that processing a more significant proportion of alternate crudes could result in reduced refinery run rates, significantly reduced production and additional capital expenditures, which could be material. Accordingly, any major disruption of our supply of crude oil from Venezuela could result in substantially lower revenues and additional volatility in our earnings and cash flow.

Our operations are subject to operational hazards and unforeseen interruptions, and we do not insure against all potential losses. Therefore, we could be seriously harmed by unexpected liabilities.

Our operations are subject to operational hazards and unforeseen interruptions such as natural disasters, adverse weather, accidents, fires, explosions, hazardous materials releases, mechanical failures and other events beyond our control. These events might result in a loss of equipment or life, injury or extensive property damage, as well as an interruption in our

operations. In the event any of our facilities are forced to shut down for a significant period of time, it may have a material adverse effect on our earnings, our other results of operations and our financial condition as a whole.

We may not be able to maintain or obtain insurance of the type and amount we desire at reasonable rates. As a result of market conditions, premiums and deductibles for certain of our insurance policies have increased substantially and could escalate further. Certain insurance coverage could become unavailable or available only for reduced amounts of coverage and at higher rates. For example, our insurance carriers require broad exclusions for losses due to terrorist acts. If we were to incur a significant liability for which we are not fully insured, such a liability could have a material adverse effect on our financial position and our ability to make distributions to our unitholders and to meet our debt service requirements.

The price volatility of crude oil and refined products can reduce our revenues and ability to make distributions to our unitholders.

Revenues associated with our asphalt operations result from the refining of crude oil into asphalt and other products and the sale of those products. The price and market value of crude oil and refined products is volatile. Our revenues will be

adversely affected by this volatility during periods of decreasing prices because of the reduction in the value and resale price of our inventory. Future price volatility could have an adverse impact on our results of operations, cash flow and ability to make distributions to our unitholders.

Our financial results are affected by volatile asphalt and intermediate product refining margins.

A large portion of our earnings subsequent to acquiring the East Coast Asphalt Operationsfrom our asphalt operations are affected by the relationship, or margin, between asphalt and other intermediate product prices and the prices for crude oil and other feedstocks. Our cost to acquire feedstocks and the price at which we can ultimately sell asphalt and other intermediate products depend upon several factors beyond our control, including regional and global supply of and demand for crude oil, asphalt and other feedstocks and intermediate and refined products. These in turn depend on, among other things, the availability and quantity of imports, the production levels of domestic and foreign suppliers, levels of intermediate and refined product inventories, U.S. relationships with foreign governments, political affairs and the extent of governmental regulation.

Additionally, crude oil prices and prices for the asphalt and intermediate products produced by the East Coast Asphalt Operationsour asphalt operations may not fluctuate consistently. Typically, increases in the prices of asphalt and intermediate products lag behind increases in the price of crude oil. Furthermore, much of the asphalt produced by the East Coast Asphalt Operationsour asphalt operations is marketed to satisfy governmental contracts. The governmental agencies with which we or our customers contract may have budgetary or other constraints that limit their ability to absorb higherincreases to asphalt prices. Our results of operations in our asphalt and fuels marketing segment will suffer if the market prices of asphalt and intermediate products do not increase to the same degreeas much as the price of crude oil. Our increased exposure to unstable commodity prices will increase the volatility of our earnings.

The price volatilityoperating results for our asphalt operations are seasonal and generally lower in the first and fourth quarters of crude oilthe year.

The selling prices of asphalt products we produce are seasonal. Asphalt demand is generally lower in the first and refinedfourth quarters of the year as compared to the second and third quarters, due to the seasonality of road construction. In addition, our natural gas costs can be higher during the winter months. Our operating results for the first and fourth calendar quarters will likely be lower than those for the second and third calendar quarters of each year as a result of this seasonality.

Competition in the asphalt industry is intense, and such competition in the markets in which we sell our asphalt products can reducecould adversely affect our revenuesearnings and ability to make distributions to our unitholders.

RevenuesOur asphalt operations compete with other refiners and with regional and national asphalt marketing companies. Many of the East Coast Asphalt Operations result from the refining of crude oil into asphalt and other products and the sale of those products. The price and market value ofthese competitors are larger, more diverse companies with greater resources, providing them advantages in obtaining crude oil and refined products is volatile. Our revenues will be adversely affected by this volatility during periods of decreasing prices because of the reductionother blendstocks and in the value and resale price of our inventory. Future price volatility could have an adverse impact on our results of operations, cash flow and ability to make distributions to our unitholders.competing through bidding process for asphalt supply contracts.

Our marketing and trading of refined products may expose us to trading losses and hedging losses, and non-compliance with our risk management policies could result in significant financial losses.

Our marketing and trading of refined products may expose us to price volatility risk for the purchase and sale of crude oil and petroleum products, including gasoline, distillates, fuel oil and asphalt. We attempt to mitigate this volatility risk through hedging, but we are still exposed to basis risk. We may also be exposed to inventory and financial liquidity risk due to the inability to trade certain products on demand or rising costs of carrying some inventories. Further, our marketing and trading activities, including any hedging activities, may cause volatility in our earnings. In addition, we will be exposed to credit risk in the event of non-performance by counterparties.

Our risk management policies may not eliminate all price risk since open trading positions will expose us to price volatility. Further, there is a risk that our risk management policies will not be complied with. Although we have designed procedures to anticipate and detect non-compliance, we cannot assure you that these steps will detect and prevent all violations of our trading policies and procedures, particularly if deception and other intentional misconduct are involved.

As a result of the risks described above, the activities associated with our marketing and trading business may expose us to volatility in earnings and financial losses, which may adversely affect our financial condition and our ability to distribute cash to our unitholders.

Hedging transactions may limit our potential gains or result in significant financial losses.

In order to manage our exposure to commodity price fluctuations associated with our refiningasphalt and fuels marketing segment, including the East Coast Asphalt Operations, we may engage in crude oil and refined product hedges, typically exchange-traded futures contracts.hedges. While intended to reduce the effects of volatile crude oil

and refined product prices, such transactions, depending on the hedging instrument used, may limit our potential gains if crude oil and refined product prices were to rise substantially over the price established by the hedge. In addition, such transactions may expose us to the risk of financial loss in certain circumstances, including instances in which:

 

production is substantially less than expected;

the counterparties to our futures contracts fail to perform under the contracts; or

there is a change in the expected differential between the underlying price in the hedging agreement and the actual prices received.

The accounting standards regarding hedge accounting are complex, and even when we engage in hedging transactions that are effective economically, these transactions may not be considered effective for accounting purposes. Accordingly, our financial statements will reflect increased volatility due to these hedges, even when there is no underlying economic impact at that point. In addition, it is not always possible for us to engage in a hedging transaction that completely mitigates our exposure to commodity prices. Our financial statements may reflect a gain or loss arising from an exposure to commodity prices for which we are unable to enter into an effective hedge.

TheWe are exposed to counterparty credit risk. Nonpayment and nonperformance by our customers, vendors or derivative counterparties could reduce our revenues, increase our expenses or otherwise negatively impact our operating results, cash flows and ability to make distributions to our unitholders.

We are subject to risks of loss resulting from nonpayment or nonperformance by our customers to whom we extend credit. In addition, nonperformance by vendors who have committed to provide us with products or services could result in higher costs or interfere with our ability to successfully conduct our business. Furthermore, nonpayment by the counterparties to our interest rate and commodity derivatives could expose us to additional interest rate or commodity price risk. Weak economic conditions and widespread financial stress could reduce the liquidity of our customers, vendors or counterparties, making it more difficult for the East Coast Asphalt Operations are seasonal and generally lowerthem to meet their obligations to us. Any substantial increase in the firstnonpayment and fourth quartersnonperformance by our customers, vendors or counterparties could have a material adverse effect on our results of operations and cash flows.

Our future financial and operating flexibility may be adversely affected by our significant leverage, our significant working capital needs, restrictions in our debt agreements and disruptions in the financial markets.

As of December 31, 2009, our consolidated debt was $1.8 billion. Among other things, our significant leverage may be viewed negatively by credit rating agencies, which could result in increased costs for us to access the capital markets. NuStar Logistics and NuPOP have senior unsecured ratings of Baa3 with Moody’s Investor Service and BBB minus with Standard & Poor’s and Fitch. Fitch, Moody’s and Standard & Poor’s have assigned NuStar Logistics and NuPOP a stable outlook. Any future downgrade of the year.

The selling prices of asphalt products we produce are seasonal. Asphalt demand is generally lowerdebt issued by these wholly owned subsidiaries could significantly increase our capital costs and adversely affect our ability to raise capital in the firstfuture. Additionally, any further ratings downgrade on the debt issued by NuStar Logistics could result in an adjustment to the interest rates on the bonds issued by NuStar Logistics in April 2008, which would significantly increase our capital costs and fourth quartersadversely affect our ability to raise capital in the future.

We require significant amounts of working capital to make purchases of crude oil and maintain necessary seasonal inventories to support our asphalt operations. We believe that our current sources of capital are adequate to meet our working capital needs. However, if our working capital needs increase more than anticipated, we may be forced to seek additional sources of capital, which may not be available or available on commercially reasonable terms.

Our five-year revolving credit agreement (the 2007 Revolving Credit Agreement) contains restrictive covenants, including a requirement that, as of the yearend of each rolling period, which consists of any period of four consecutive fiscal quarters, we maintain a consolidated debt coverage ratio (consolidated indebtedness to consolidated EBITDA, as compareddefined in the 2007 Revolving Credit Agreement) not to exceed 5.00-to-1.00. Failure to comply with any of the secondrestrictive covenants in the 2007 Revolving Credit Agreement will result in a default under the terms of our credit agreement and third quarters duecould result in acceleration of this and possibly other indebtedness.

Debt service obligations, restrictive covenants in our credit facilities and the indentures governing our outstanding senior notes and maturities resulting from this leverage may adversely affect our ability to the seasonality of road construction.finance future operations, pursue acquisitions and fund other capital needs and our ability to pay cash distributions to unitholders. In addition, this leverage may make our natural gas costs canresults of operations more susceptible to adverse economic or operating conditions. For example, during an

event of default under any of our debt agreements, we would be higher duringprohibited from making cash distributions to our unitholders.

If our lenders file for bankruptcy or experience severe financial hardship, they may not honor their pro rata share of our borrowing requests under the winter months. Our operating results for the first2007 Revolving Credit Agreement, which may significantly reduce our available borrowing capacity and, fourth calendar quarters may be lower than those for the second and third calendar quarters of each year as a result, materially adversely affect our financial condition and ability to pay distributions to unitholders.

Additionally, we may not be able to access the capital markets in the future at economically attractive terms, which may adversely affect our future financial and operating flexibility and our ability to pay cash distributions at current levels.

Increases in interest rates could adversely affect our business and the trading price of this seasonality.our units.

We have significant exposure to increases in interest rates. At December 31, 2009, we had approximately $1.8 billion of consolidated debt, of which $1.0 billion was at fixed interest rates and $0.8 billion was at variable interest rates after giving effect to interest rate swap agreements. Our results of operations, cash flows and financial position could be materially adversely affected by significant increases in interest rates above current levels. Further, the trading price of our units is sensitive to changes in interest rates and any rise in interest rates could adversely impact such trading price.

We could be subject to damages based on claims brought against us by our customers or lose customers as a result of the failure of our products to meet certain quality specifications.

Our specialty asphalt products are produced to precise customer specifications. If a product fails to perform in a manner consistent with the detailed quality specifications required by the customer, the customer could seek replacement of the product or damages for costs incurred as a result of the product failing to perform as guaranteed. A successful claim or series of claims against us could result in a loss of one or more customerscustomers.

If we are unable to complete capital projects at their expected costs and/or in a timely manner, or if the market conditions assumed in our project economics deteriorate, our financial condition, results of operations, or cash flows could be affected materially and diminishadversely.

Delays or cost increases related to capital spending programs involving construction of new facilities (or improvements and repairs to our existing facilities) could adversely affect our ability to make distributionsachieve forecasted operating results. Although we evaluate and monitor each capital spending project and try to unitholders.anticipate difficulties that may arise, such delays or cost increases may arise as a result of factors that are beyond our control, including:

denial or delay in issuing requisite regulatory approvals and/or permits;

unplanned increases in the cost of construction materials or labor;

disruptions in transportation of modular components and/or construction materials;

severe adverse weather conditions, natural disasters, or other events (such as equipment malfunctions explosions, fires, spills) affecting our facilities, or those of vendors and suppliers;

shortages of sufficiently skilled labor, or labor disagreements resulting in unplanned work stoppages;

market-related increases in a project’s debt or equity financing costs; and/or

nonperformance by, or disputes with, vendors, suppliers, contractors, or sub-contractors involved with a project.

Our forecasted operating results also are based upon our projections of future market fundamentals that are not within our control, including changes in general economic conditions, availability to our customers of attractively priced alternative supplies of crude oil and refined products and overall customer demand.

Potential future acquisitions and expansions, if any, may increase substantially the level of our indebtedness and contingent liabilities, and we may be unable to integrate them effectively into our existing operations.

From time to time, we evaluate and acquire assets and businesses that we believe complement or diversify our existing assets and businesses. Acquisitions may require substantial capital or the incurrence of substantial indebtedness. If we consummate any future material acquisitions, our capitalization and results of operations may change significantly.

Acquisitions and business expansions involve numerous risks, including difficulties in the assimilation of the assets and operations of the acquired businesses, inefficiencies and difficulties that arise because of unfamiliarity with new assets and the businesses associated with them and new geographic areas. Further, unexpected costs and challenges may arise whenever businesses with different operations or management are combined and we may experience unanticipated delays in realizing the benefits of an acquisition. In some cases, we have indemnified the previous owners and operators of acquired assets.

Following an acquisition, we may discover previously unknown liabilities associated with the acquired business for which we have no recourse under applicable indemnification provisions. In addition, the terms of an acquisition may require us to assume certain prior known or unknown liabilities for which we may not be indemnified or have adequate insurance.

Climate change legislation and regulatory initiatives may decrease demand for the products we store, transport and sell and increase our operating costs.

Recent scientific studies have suggested that emissions of certain gases, commonly referred to as “greenhouse gases” and including carbon dioxide and methane, may be contributing to warming of the Earth’s atmosphere. In response to such studies, the U.S. Congress is actively considering legislation to reduce emissions of greenhouse gases. In addition, at least one-third of the states, either individually or through multi-state regional initiatives, have already taken legal measures to reduce emissions of greenhouse gases, primarily through the planned development of greenhouse gas emission inventories and/or greenhouse gas cap and trade programs. As an alternative to reducing emission of greenhouse gases under cap and trade programs, Congress may consider the implementation of a program to tax the emission of carbon dioxide and other greenhouse gases. In December 2009, the EPA issued an endangerment finding that greenhouse gases may reasonably be anticipated to endanger public health and welfare and are a pollutant to be regulated under the Clean Air Act. Passage of climate change legislation or other regulatory initiatives by Congress or various states of the U.S. or the adoption of regulations by the EPA or analogous state agencies that regulate or restrict emissions of greenhouse gases in areas in which we conduct business, could result in changes to the demand for the products we store, transport and sell, and could increase the costs of our operations, including costs to operate and maintain our facilities, install new emission controls on our facilities, acquire allowances to authorize our greenhouse gas emissions, pay any taxes related to our greenhouse gas emissions and administer and manage a greenhouse gas emissions program. We may be unable to recover any such lost revenues or increased costs in the rates we charge our customers, and any such recovery may depend on events beyond our control, including the outcome of future rate proceedings before the FERC and the provisions of any final legislation or regulations. Reductions in our revenues or increases in our expenses as a result of climate control initiatives could have adverse effects on our business, financial position, results of operations and prospects.

We may have liabilities from our refining assets that pre-exist our acquisition of the East Coast Asphalt Operations,those assets, but that may not be covered by indemnification rights we will have against the sellers of the assets.

Some of theour assets included in the East Coast Asphalt Operations have been used for many years to refine, transport and store asphaltcrude oil and refined products. Releases may have occurred in the past whichthat could require costly future remediation. If a significant release or event occurred in the past, the liability for which was not retained by the seller, or for which indemnification from the seller is not available, it could adversely affect our financial position and results of operations.

Competition in the asphalt industry is intense, and such competition in the markets in which we sell our asphalt products could adversely affect our earnings and ability to make distributions to our unitholders.

The East Coast Asphalt Operations compete with other refiners and with regional and national asphalt marketing companies. Many of these competitors are larger, more diverse companies with greater resources, providing them advantages in obtaining crude oil and other blendstocks and in competing through bidding process for asphalt supply contracts.

Our future financial and operating flexibility may be adversely affected by our significant leverage, the significant working capital needs associated with the East Coast Asphalt Operations, restrictions in our debt agreements and recent disruptions in the financial markets.

As of December 31, 2008, our consolidated debt was $1.9 billion. Among other things, our significant leverage may be viewed negatively by credit rating agencies, which could result in increased costs for us to access the capital markets. NuStar Logistics and NuPOP have senior unsecured ratings of Baa3 with Moody’s Investor Service and BBB minus with Standard & Poors and Fitch, all with a negative outlook. The negative outlook was assigned by the credit rating agencies as a result of our acquisition of the East Coast Asphalt Operations. Any future downgrade of the debt issued by these

wholly owned subsidiaries could significantly increase our capital costs and adversely affect our ability to raise capital in the future. Additionally, any further ratings downgrade on the debt issued by NuStar Logistics could result in an adjustment to the interest rates on the bonds issued by NuStar Logistics in April 2008, which would significantly increase our capital costs and adversely affect our ability to raise capital in the future.

We require significant amounts of working capital to operate the East Coast Asphalt Operations. In particular, we use working capital to make purchases of crude oil and maintain necessary seasonal inventories at the East Coast Asphalt Operations. We believe that our current sources of capital are adequate to meet our working capital needs. However, if our working capital needs increase more than anticipated, we may be forced to seek additional sources of capital, which may not be available on commercially reasonable terms. In addition, in the event our access to capital resources is significantly reduced, we may not be able to adequately fund our working capital needs for those assets.

Our five-year revolving credit agreement (the 2007 Revolving Credit Agreement) contains restrictive covenants, including a requirement that, as of the end of each rolling period, which consists of any period of four consecutive fiscal quarters, we maintain a consolidated debt coverage ratio (consolidated indebtedness to consolidated EBITDA, as defined in the 2007 Revolving Credit Agreement) not to exceed 5.00-to-1.00. Failure to comply with any of the restrictive covenants in the 2007 Revolving Credit Agreement will result in a default under the terms of our credit agreement and could result in acceleration of this indebtedness. We believe that we are in compliance with all ratios and covenants in the 2007 Revolving Credit Agreement as of December 31, 2008.

Debt service obligations, restrictive covenants in our credit facilities and the indentures governing our outstanding senior notes and maturities resulting from this leverage may adversely affect our ability to finance future operations, pursue acquisitions and fund other capital needs and our ability to pay cash distributions to unitholders. In addition, this leverage may make our results of operations more susceptible to adverse economic or operating conditions. For example, during an event of default under any of our debt agreements, we would be prohibited from making cash distributions to our unitholders.

As of December 31, 2008, we had $610.7 million available for borrowing under the 2007 Revolving Credit Agreement, which assumes no remaining available commitment from Lehman Brothers Bank, FSB (LB Bank), a subsidiary of Lehman Brothers Holdings Inc. (Lehman). As a result of Lehman’s bankruptcy filing, LB Bank has elected not to fund its pro rata share of any future borrowings we request, which reduces the total commitment under the 2007 Revolving Credit Agreement to approximately $1.2 billion. If other lenders under the 2007 Revolving Credit Agreement file for bankruptcy or experience severe financial hardship due to recent disruptions and steep declines in the global financial markets and generally severely tightening credit supply, they may not honor their pro rata share of our borrowing requests, which may significantly reduce our available borrowing capacity and, as a result, materially adversely affect our financial condition and ability to pay distributions to unitholders.

Additionally, we may not be able to access the capital markets in the future at economically attractive terms, which may adversely affect our future financial and operating flexibility and our ability to pay cash distributions at current levels.

Increases in interest rates could adversely affect our business and the trading price of our units.

We have significant exposure to increases in interest rates. At December 31, 2008, we had approximately $1.9 billion of consolidated debt, of which $1.1 billion was at fixed interest rates and $0.8 billion was at variable interest rates after giving effect to interest rate swap agreements. Our results of operations, cash flows and financial position could be materially adversely affected by significant increases in interest rates above current levels. Further, the trading price of our units is sensitive to changes in interest rates and any rise in interest rates could adversely impact such trading price.

We may not be able to integrate effectively and efficiently with any future businesses or operations we may acquire. Any future acquisitions may substantially increase the levels of our indebtedness and contingent liabilities.

Part of our business strategy includes acquiring additional assets that complement our existing asset base and distribution capabilities or provide entry into new markets. We may not be able to identify suitable acquisitions, or we may not be able to purchase or finance any acquisitions on terms that we find acceptable. Additionally, we compete against other companies for acquisitions, and we cannot assure unitholders that we will be successful in the acquisition of any assets or businesses appropriate for our growth strategy. Our capitalization and results of operations may change significantly as a result of future acquisitions, and unitholders will not have the opportunity to evaluate the economic, financial and other relevant information that we will consider in connection with any future acquisitions. Unexpected costs or challenges may arise whenever businesses with different operations and management are combined. For example, the incurrence of

substantial unforeseen environmental and other liabilities, including liabilities arising from the operation of an acquired business or asset prior to our acquisition for which we are not indemnified or for which indemnity is inadequate, may adversely affect our ability to realize the anticipated benefit from an acquisition. Inefficiencies and difficulties may arise because of unfamiliarity with new assets and new geographic areas of any acquired businesses. Successful business combinations will require our management and other personnel to devote significant amounts of time to integrating the acquired businesses with our existing operations. These efforts may temporarily distract their attention from day-to-day business, the development or acquisition of new properties and other business opportunities. If we do not successfully integrate any past or future acquisitions, or if there is any significant delay in achieving such integration, our business and financial condition could be adversely affected.

Our operations are subject to federal, state and local laws and regulations relating to environmental protection and operational safety that could require us to make substantial expenditures.

Our operations are subject to increasingly stringent environmental and safety laws and regulations. Refining, petroleum and transporting and storing petroleum and other products, such as specialty liquids, produces a risk that these products may be released into the environment, potentially causing substantial expenditures for a response action, significant government penalties, liability to government agencies for damages to natural resources, damages, personal injury or property damages to private parties and significant business interruption. We own or lease a number of properties that have been used to store or distribute refined products for many years. Many of these properties were operated by third parties whose handling, disposal or release of hydrocarbons and other wastes was not under our control.

If we were to incur a significant liability pursuant to environmental or safety laws or regulations, such a liability could have a material adverse effect on our financial position, our ability to make distributions to our unitholders and our ability to meet our debt service requirements. Please read Item 3. “Legal Proceedings” and Note 15 of Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data.”

Some of our pipelines are interstate common carrier pipelines, subject to regulation by the FERC under the ICA.FERC.

UnderThe FERC regulates the ICA, common carrier pipelines must maintain tariffs on file with the FERC. These tariffs include thetariff rates we charge for providing transportation servicesinterstate oil movements on our common carrier pipelines as well as the rulespipelines. Shippers may protest our pipeline tariff filings, and regulations governing these services. The ICA requires, among other things, that such rates on interstate common carrier pipelines be “just and reasonable” and nondiscriminatory.

The EPAct, among other things, deems “just and reasonable,” within the meaning of the ICA, any oil pipeline rate in effect for the 365-day period ending on the date of the enactment of EPAct if the rate in effect was not subject to protest, investigation or complaint during such 365-day period. Essentially, any such rates are “grandfathered in” by the EPAct. The EPAct further protects any rate meeting this requirement from complaint unless the complainant can show a substantial change occurred after the enactment of EPAct in the economic circumstances of the oil pipeline that were the basis or in the nature of the services provided that were bases for the rate.

The ICA permits persons with a substantial economic interest in any new tariff filing to challenge a tariff publication. The FERC will determine whether to suspend the tariff for a period of up to seven months and initiate a formal investigation. If, upon completion of an investigation, the FERC finds that themay investigate new or changed tariff rates. Further, other than for rates set under market-based rate is unlawful, it is authorizedauthority, the FERC may order refunds of amounts collected under newly filed rates that are determined by the FERC to require the carrier to refund the revenuesbe in excess of a just and reasonable level when taking into consideration our pipeline system’s cost of service. In addition, shippers may challenge by complaint the priorlawfulness of tariff collected during the pendency of the investigation.rates that have become final and effective. The FERC may also investigate uponsuch rates absent shipper complaint. If existing rates challenged by complaint or on its own motion, rates that are alreadydetermined by the FERC to be in effectexcess of a just and order a carrier to change its rates prospectively. Upon an appropriate showing,reasonable level when taking into consideration our pipeline

system’s cost of service, a shipper may obtain reparations for damages sustained during the two years prior to the filing of a complaint.

We use various FERC-authorized rate change methodologies for our interstate pipelines, including indexing, cost-of-service rates, market-based rates and settlement rates. Typically, we annually adjust our rates in accordance with FERC indexing methodology, which currently allows a pipeline to change their rates within prescribed ceiling levels that are tied to an inflation index. The current index (which runs through June 30, 2011) is measured by the year-over-year change in the Bureau of Labor’s producer price index for finished goods, plus 1.3%. Shippers may protest rate increases made within the ceiling levels, but such protests must show that the portion of the rate increase resulting from application of the index is substantially in excess of the pipeline’s increase in costs from the previous year. However, if the index results in a negative adjustment, we will typically beare required to reduce any rates that exceed the new maximum allowable rate. In addition, changes in the index might not be large enough to fully reflect actual increases in our costs. If the FERC’s rate-making methodologies change, any such change or new methodologies could result in rates that generate lower revenues and cash flow and could adversely affect our ability to make distributions to our unitholders and to meet our debt service

requirements. Additionally, competition constrains our rates in various markets. As a result, we may from time to time be forced to reduce some of our rates to remain competitive.

Changes to FERC rate-making principles could have an adverse impact on our ability to recover the full cost of operating our pipeline facilities and our ability to make distributions to our unitholders.

In May 2005, the FERC issued a statement of general policy stating it will permit pipelines to include in cost of service a tax allowance to reflect actual or potential tax liability on their public utility income attributable to all partnership or limited liability company interests, if the ultimate owner of the interest has an actual or potential income tax liability on such income. Whether a pipeline’s owners have such actual or potential income tax liability will be reviewed by the FERC on a case-by-case basis. Although the newthis policy is generally favorable for pipelines that are organized as pass-through entities, it still entails rate risk due to the case-by-case review requirement. The newThis tax allowance policy and the FERC’s application of that policy were appealed to the U.S. Court of Appeals for the District of Columbia Circuit (D.C. Court), and, on May 29, 2007, the D.C. Court issued an opinion upholding the FERC’s tax allowance policy.

In December 2006, the FERC issued an order addressing income tax allowance in rates, in which it reaffirmed prior statements regarding its income tax allowance policy, but raised a new issue regarding the implications of the FERC’s policy statement for publicly traded partnerships. The FERC noted that the tax deferral features of a publicly traded partnership may cause some investors to receive, for some indeterminate duration, cash distributions in excess of their taxable income, creating an opportunity for those investors to earn additional return, funded by ratepayers. Responding to this concern, FERC adjusted the equity rate of return of the pipeline at issue downward based on the percentage by which the publicly traded partnership’s cash flow exceeded taxable income. Requests for rehearing of the order are currently pending before the FERC.

Because the extent to which an interstate oil pipeline is entitled to an income tax allowance is subject to a case-by-case review at the FERC, the level of income tax allowance to which we will ultimately be entitled is not certain. Although the FERC’s current income tax allowance policy is generally favorable for pipelines that are organized as pass-through entities, it still entails rate risks due to the case-by-case review requirement. How the FERC’s policy statement is applied in practice to pipelines owned by publicly traded partnerships could impose limits on our ability to include a full income tax allowance in cost of service.

The FERC instituted a rulemaking proceeding in July 2007 to determine whether any changes should be made to the FERC’s methodology for determining pipeline equity returns to be included in cost-of-service based rates. The FERC determined that it would retain its current methodology for determining return on equity but that, when stock prices and cash distributions of tax pass-through entities are used in the return on equity calculations, the growth forecasts for those entities should be reduced by 50%. Despite the FERC’s determination, some complainants in rate proceedings have advocated that the FERC disallow the full use of cash distributions in the return on equity calculation. If the FERC were to disallow the use of full cash distributions in the return on equity calculation, such a substantial portion ofresult might adversely affect our income tax allowance, it is possible that the maximum rates that could be charged could decrease from current levels.ability to achieve a reasonable return.

The rates that we may charge on our interstate ammonia pipeline are subject to regulation by the STB.

The STB, a part of the U.S. Department of Transportation,DOT, has jurisdiction over interstate pipeline transportation and rate regulations of anhydrous ammonia. Transportation rates must be reasonable, and a pipeline carrier may not unreasonably discriminate among its shippers. If the STB finds that a carrier’s rates violate these statutory commands, it may prescribe a reasonable rate. In

determining a reasonable rate, the STB will consider, among other factors, the effect of the rate on the volumes transported by that carrier, the carrier’s revenue needs and the availability of other economic transportation alternatives. The STB does not provide rate relief unless shippers lack effective competitive alternatives. If the STB determines that effective competitive alternatives are not available and we hold market power, then we may be required to show that our rates are reasonable.

Increases in natural gas and power prices could adversely affect our ability to make distributions to our unitholders.

Power costs constitute a significant portion of our operating expenses. For the year ended December 31, 2008,2009, our power costs equaled approximately $61.9$48.1 million, or 14.0%10% of our operating expenses for the year. In addition, $31.3$17.7 million of power costs were capitalized into inventory related to our asphalt refineries, which will be expensed into cost of product sales as the inventory is sold. We use mainly electric power at our pipeline pump stations, terminals and refineries, and such electric power is furnished by various utility companies that use primarily natural gas to generate electricity. Accordingly, our power costs typically fluctuate with natural gas prices. Increases in natural gas prices may cause our power costs to increase further. If natural gas prices increase, our cash flows may be adversely affected, which could adversely affect our ability to make distributions to our unitholders.

Terrorist attacks and the threat of terrorist attacks have resulted in increased costs to our business. Continued hostilities in the Middle East or other sustained military campaigns may adversely impact our results of operations.

Increased security measures we have taken as a precaution against possible terrorist attacks have resulted in increased costs to our business. Uncertainty surrounding continued hostilities in the Middle East or other sustained military campaigns may affect our operations in unpredictable ways, including disruptions of crude oil supplies and markets for refined products, the possibility that infrastructure facilities could be direct targets of, or indirect casualties of, an act of terror and instability in the financial markets that could restrict our ability to raise capital.

Our cash distribution policy may limit our growth.

Consistent with the terms of our partnership agreement, we distribute our available cash to our unitholders each quarter. In determining the amount of cash available for distribution, our management sets aside cash reserves, which we use to fund our growth capital expenditures. Additionally, we have relied upon external financing sources, including commercial borrowings and other debt and equity issuances, to fund our acquisition capital expenditures. Accordingly, to the extent we do not have sufficient cash reserves or are unable to finance growth externally, our cash distribution policy will significantly impair our ability to grow. In addition, to the extent we issue additional units in connection with any acquisitions or growth capital expenditures, the payment of distributions on those additional units may increase the risk that we will be unable to maintain or increase our current per unit distribution level.

NuStar GP Holdings may have conflicts of interest and limited fiduciary responsibilities, which may permit it to favor its own interests to the detriment of our unitholders.

NuStar GP Holdings currently indirectly owns our general partner and as of December 31, 2009, an aggregate 18.5%16.7% limited partner interest in us. Conflicts of interest may arise between NuStar GP Holdings and its affiliates, including our general partner, on the one hand, and us and our limited partners, on the other hand. As a result of these conflicts, the general partner may favor its own interests and the interests of its affiliates over the interests of the unitholders. These conflicts include, among others, the following situations:

 

Our general partner is allowed to take into account the interests of parties other than us, such as NuStar GP Holdings, in resolving conflicts of interest, which has the effect of limiting its fiduciary duty to the unitholders;

Our general partner may limit its liability and reduce its fiduciary duties, while also restricting the remedies available to unitholders. As a result of purchasing our common units, unitholders have consented to some actions and conflicts of interest that might otherwise constitute a breach of fiduciary or other duties under applicable state law;

Our general partner determines the amount and timing of asset purchases and sales, capital expenditures, borrowings, issuance of additional limited partner interests and reserves, each of which can affect the amount of cash that is paid to our unitholders;

Our general partner determines in its sole discretion which costs incurred by NuStar GP Holdings and its affiliates are reimbursable by us;

Our general partner may cause us to pay the general partner or its affiliates for any services rendered on terms that are fair and reasonable to us or enter into additional contractual arrangements with any of these entities on our behalf;

Our general partner decides whether to retain separate counsel, accountants or others to perform services for us; and

In some instances, our general partner may cause us to borrow funds in order to permit the payment of distributions.

Our partnership agreement gives the general partner broad discretion in establishing financial reserves for the proper conduct of our business, including interest payments. These reserves also will affect the amount of cash available for distribution.

TAX RISKS TO OUR UNITHOLDERS

If we were treated as a corporation for federal or state income tax purposes, then our cash available for distribution to unitholders would be substantially reduced.

The anticipated after-tax benefit of an investment in our units depends largely on our being treated as a partnership for federal income tax purposes. We have not requested, and do not plan to request, a ruling from the IRS on this matter.

If we were treated as a corporation for federal income tax purposes, we would pay federal income tax on our taxable income at the corporate tax rate, which is currently a maximum of 35%. Distributions to unitholders would generally be taxed again as corporate distributions, and no income, gains, losses, deductions or credits would flow through to unitholders. Thus, treatment of us as a corporation would result in a material reduction in our anticipated cash flow and after-tax return to unitholders, likely causing a substantial reduction in the value of our units.

Current law may change, causing us to be treated as a corporation for federal income tax purposes or otherwise subjecting us to entity-level taxation. In addition, because of widespread state budget deficits, several states are evaluating ways to subject partnerships to entity level taxation through the imposition of state income, franchise or other forms of taxation. For example, the State of New Jersey imposes a state level tax which we currently pay at the maximum amount of $250,000. Partnerships and limited liability companies, unless specifically exempted, are also subject to a state-level tax imposed on Texas source revenues. Specifically, the Texas margin tax is imposed at a maximum effective tax rate of 0.7% of our gross revenue or 1% of our gross margin that is apportioned to Texas. Imposition of any entity-level tax on us by Texas, or additional states we operate in will reduce the cash available for distribution to our unitholders.

A successful IRS contest of the federal income tax positions we take may adversely impact the market for our units, and the costs of any contest will reduce cash available for distribution to our unitholders.

The IRS may adopt positions that differ from the positions we take, even positions taken with the advice of counsel. It may be necessary to resort to administrative or court proceedings to sustain some or all of the positions we take. A court

may not agree with all of the positions we take. Any contest with the IRS may materially and adversely impact the market for our units and the prices at which they trade. In addition, the costs of any contest between us and the IRS will result in a reduction in cash available for distribution to our unitholders. Moreover, the costs of any contest between us and the IRS will result in a reduction in cash available for distribution to our unitholders and thus will be borne indirectly by our unitholders and our general partner.

Even if unitholders do not receive any cash distributions from us, they will be required to pay taxes on their respective share of our taxable income.

Unitholders will be required to pay federal income taxes and, in some cases, state and local income taxes on the unitholder’s respective share of our taxable income, whether or not such unitholder receives cash distributions from us. Unitholders may not receive cash distributions from us equal to the unitholder’s respective share of our taxable income or even equal to the actual tax liability that results from the unitholder’s respective share of our taxable income.

The sale or exchange of 50% or more of our capital and profits interests, within a 12-month period, will result in the termination of our partnership for federal income tax purposes.

A termination would, among other things, result in the closing of our taxable year for all unitholders and would result in a deferral of depreciation and cost recovery deductions allowable in computing our taxable income. If our partnership were terminated for federal income tax purposes, a NuStar Energy unitholder would be allocated an increased amount of federal taxable income for the year in which the partnership is considered terminated and the subsequent years as a percentage of the cash distributed to the unitholder with respect to that period.

Tax gain or loss on the disposition of our units could be different than expected.

If a unitholder sells units, the unitholder will recognize gain or loss equal to the difference between the amount realized and that unitholder’s tax basis in those units. Prior distributions to the unitholder in excess of the total net taxable income

the unitholder was allocated for a unit, which decreased the tax basis in that unit, will, in effect, become taxable income to the unitholder if the unit is sold at a price greater than the tax basis in that unit, even if the price the unitholder receives is less than the original cost. A substantial portion of the amount realized, whether or not representing gain, may be ordinary income to the selling unitholder.

Tax-exempt entities and foreign persons face unique tax issues from owning units that may result in adverse tax consequences to them.

Investment in units by tax-exempt entities, such as individual retirement accounts (known as IRAs) and non-U.S. persons raises issues unique to them. For example, virtually all of our income allocated to organizations exempt from federal income tax, including individual retirement accounts and other retirement plans, will be unrelated business taxable income and will be taxable to them. Distributions to non-U.S. persons will be reduced by withholding taxes at the highest applicable effective tax rate, and non-U.S. persons will be required to file U.S. federal income tax returns and pay tax on their share of our taxable income.

We will treat each purchaser of our units as having the same tax benefits without regard to the units purchased. The IRS may challenge this treatment, which could adversely affect the value of our units.

Because we cannot match transferors and transferees of units, we will adopt depreciation and amortization positions that may not conform to all aspects of existing Treasury regulations. A successful IRS challenge to those positions could adversely affect the amount of tax benefits available to unitholders. It also could affect the timing of these tax benefits or the amount of gain from any sale of units and could have a negative impact on the value of our units or result in audit adjustments to a unitholder’s tax returns.

Unitholders will likely be subject to state and local taxes and return filing requirements as a result of investing in our units.

In addition to federal income taxes, unitholders will likely be subject to other taxes, such as state and local income taxes, unincorporated business taxes and estate, inheritance or intangible taxes that are imposed by various jurisdictions in which we do business or own property. Unitholders will likely be required to file state and local income tax returns and pay state and local income taxes in some or all of these various jurisdictions. Further, unitholders may be subject to penalties for failure to comply with those requirements. We may own property or conduct business in other states or foreign countries in the future. It is each unitholder’s responsibility to file all federal, state or local tax returns.

We have adopted certain valuation methodologies that may result in a shift of income, gain, loss and deduction between the general partner and the unitholders. The IRS may challenge this treatment, which could adversely affect the value of our common units.

When we issue additional units or engage in certain other transactions, we determine the fair market value of our assets and allocate any unrealized gain or loss attributable to our assets to the capital accounts of our unitholders and our general partner. Our methodology may be viewed as understating the value of our assets. In that case, there may be a shift of income, gain, loss and deduction between certain unitholders and the general partner, which may be unfavorable to such unitholders. Moreover, under our current valuation methods, subsequent purchasers of common units may have a greater portion of their Internal Revenue Code Section 743(b) adjustment allocated to our tangible assets and a lesser portion allocated to our intangible assets. The IRS may challenge our valuation methods, our methods, allocation of the Section 743(b) adjustment attributable to our tangible and intangible assets, and allocations of income, gain, loss and deduction between the general partner and certain of our unitholders.

A successful IRS challenge to these methods or allocations could adversely affect the amount of taxable income or loss being allocated to our unitholders. It also could affect the amount of gain from our unitholders’ sale of common units and could have a negative impact on the value of the common units or result in audit adjustments to our unitholders’ tax returns without the benefit of additional deductions.

PROPERTIES

Our principal properties are described above under the caption “Segments,” and that information is incorporated herein by reference. We believe that we have satisfactory title to all of our assets. Although title to these properties is subject to encumbrances in some cases, such as customary interests generally retained in connection with acquisition of real property, liens related to environmental liabilities associated with historical operations, liens for current taxes and other burdens and easements, restrictions and other encumbrances to which the underlying properties were subject at the time of acquisition by us or our predecessors, we believe that none of these burdens will materially detract from the value of these properties or from our interest in these properties or will materially interfere with their use in the operation of our business. In addition, we believe that we have obtained sufficient right-of-way grants and permits from public authorities and private parties for us to operate our business in all material respects as described in this report. We perform scheduled maintenance on all of our refineries, pipelines, terminals, crude oil tanks and related equipment and make repairs and replacements when necessary or appropriate. We believe that our refineries, pipelines, terminals, crude oil tanks and related equipment have been constructed and are maintained in all material respects in accordance with applicable federal, state and local laws and the regulations and standards prescribed by the American Petroleum Institute, the DOT and accepted industry practice.

ITEM 1B. UNRESOLVED STAFF COMMENTS

None.

ITEM 3. LEGAL PROCEEDINGS

We are named as a defendant in litigation relating to our normal business operations, including regulatory and environmental matters. We are insured against various business risks to the extent we believe is prudent; however, we cannot assure you that the nature and amount of such insurance will be adequate, in every case, to protect us against liabilities arising from future legal proceedings as a result of our ordinary business activity.

GRACE ENERGY CORPORATION MATTER

In 1997, Grace Energy Corporation (Grace Energy) sued subsidiaries of Kaneb Pipe Line Partners, L.P. (KPP) and Kaneb Services LLC (KSL and, collectively with KPP and their respective subsidiaries, Kaneb) in Texas state court. The complaint sought recovery of the cost of remediation of fuel leaks in the 1970s from a pipeline that had once connected a former Grace Energy terminal with Otis Air Force Base in Massachusetts (Otis AFB). Grace Energy alleges the Otis AFB pipeline and related environmental liabilities had been transferred in 1978 to an entity that was part of Kaneb’s acquisition of Support Terminal Services, Inc. and its subsidiaries from Grace Energy in 1993. Kaneb contends that it did not acquire the Otis AFB pipeline and never assumed any responsibility for any associated environmental damage.

In 2000, the court entered final judgment that: (i) Grace Energy could not recover its own remediation costs of $3.5 million, (ii) Kaneb owned the Otis AFB pipeline and its related environmental liabilities and (iii) Grace Energy was awarded $1.8 million in attorney costs. Both Kaneb and Grace Energy appealed the final judgment of the trial court to the Texas Court of Appeals in Dallas. In 2001, Grace Energy filed a petition in bankruptcy, which created an automatic stay of actions against Grace Energy. In September 2008, Grace Energy filed its Joint Plan of Reorganization and Disclosure Statement. We have sought relief from the bankruptcy stay in order to pursue our appellate rights.

The Otis AFB is a part of a Superfund Site pursuant to the Comprehensive Environmental Response Compensation and Liability Act (CERCLA). The site contains a number of groundwater contamination plumes, two of which are allegedly associated with the Otis AFB pipeline. Relying on the final judgment of the Texas state court assigning ownership of the Otis AFB pipeline to Kaneb, the U.S. Department of Justice (the DOJ) advised Kaneb in 2001 that it intends to seek reimbursement from Kaneb for the remediation costs associated with the two plumes. In November 2008, the DOJ forwarded information to us indicating that the past and estimated future remediation expenses associated with one plume are $71.9 million. The DOJ has indicated that they will not seek recovery of remediation costs for the second plume. The DOJ has not filed a lawsuit against us related to this matter, and we have not made any payments toward costs incurred by the DOJ. We are currently in settlement discussions with other potentially responsible parties and the DOJ and a change in our estimate of this liability may occur in the near term. However, any settlement agreement that is reached must be approved by multiple parties and requires the approval of the bankruptcy court and the federal district court. We cannot currently estimate when or if a settlement will be finalized.

ERES MATTER

In August 2008, Eres N.V. (Eres) forwarded a demand for arbitration to CITGO Asphalt Refining Company (CARCO), CITGO Petroleum Corporation (CITGO), NuStar Asphalt Refining, LLC (NuStar Asphalt) and NuStar Marketing LLC (NuStar Marketing, and together with CARCO, CITGO and NuStar Asphalt, the Defendants) contending that the Defendants are in breach of a tanker voyage charter party agreement, dated November 2004, between Eres and CARCO (the Charter Agreement). The Charter Agreement provides for CARCO’s use of Eres’ vessels for the shipment of asphalt. Eres contends that NuStar Asphalt and/or NuStar Marketing (together, the NuStar Entities) assumed the Charter Agreement when NuStar Asphalt purchased the CARCO assets, and that the Defendants have failed to perform under the Charter Agreement since January 1, 2008. Eres seeks to compel the Defendants to arbitrate a breach of contract claim in which Eres values its damages at approximately $78.1 million. CITGO/CARCO hasalso contend that the NuStar Entities assumed the Eres contract and they have demanded that the NuStar Asphalt and NuStar MarketingEntities defend and indemnify itthem against Eres’ claims. Eres’ motion to compel arbitration and CITGO/CARCO’s indemnity claims and has filed a lawsuit in the Harris County District Court, Harris County, Texas, seeking to recover on its indemnity claim. This lawsuit has been removed and isare currently pending in the U.S. District Court for the Southern District of Texas. In connection with the demand for arbitration, Eres filed a complaint in the U.S. District Court for the Southern District of New York (SDNY) seeking to require the Defendants to arbitrate the dispute and seeking to attach the banking funds of CARCO and NuStar Asphalt (including cash, escrow funds, credits, debts, wire transfers, electronic funds transfers, accounts, letters of credit, freights and charter hire) within the SDNY in amounts of approximately $78.1 million pending resolution of arbitration between Eres and the Defendants. To date, no funds of NuStar Asphalt have been attached. We intend to vigorously defend against these claims.

ENVIRONMENTAL AND SAFETY COMPLIANCE MATTERS

With respect to the environmental proceedings listed below, if any one or more of them were decided against us, we believe that it would not have a material effect on our consolidated financial position. However, it is not possible to predict the ultimate outcome of any of these proceedings or whether such ultimate outcome may have a material effect on our consolidated financial position. We report these proceedings to comply with Securities and Exchange Commission regulations, which require us to disclose proceedings arising under federal, state or local provisions regulating the discharge of materials into the environment or protecting the environment if we reasonably believe that such proceedings will result in monetary sanctions of $100,000 or more.

In particular, in September 2008, the Illinois State Attorney General’s Office proposed penalties totaling $240,000 related to a leak at a storage terminal in Chillicothe, Illinois that we previously owned through a joint venture with Center Oil Company until we sold our interest in October 2006. The leak was originally discovered and reported to the Illinois Emergency Management Agency (IEMA) in 2002. We are currently in settlement negotiations with IEMA to resolve this matter.

In December 2005, the U.S. Department of Transportation, Office of Pipeline Safety (OPS) proposed penalties totaling $255,000 based on alleged violations of various pipeline safety requirements in the McKee System. We are currently in settlement negotiations with OPS to resolve this matter.

In November 2006, agents of the U.S. Environmental Protection Agency (the EPA) presented a search warrant issued by a U.S. District Court at one of our terminals. Since then, we have been served with additional subpoenas. The search warrant and subpoenas all sought information regarding allegations of potential illegal conduct by us, certain of our subsidiaries and/or our employees concerning compliance with certain environmental and safety laws and regulations. We have cooperated fully with the U.S. Attorney and the EPA in producing documents in response to the subpoenas. Although the U.S. Attorney has indicated that they intend to seek criminal penalties and fines as a result of alleged violations of environmental laws at the terminal, we are currently in negotiations with the U.S. Attorney and the EPA to resolve this matter. There can be no assurances that the conclusion of the U.S. Attorney’s and the EPA’s investigation will not result in a determination that we violated applicable laws. If we are found to have violated such laws, we could be subject to fines, civil penalties and criminal penalties. A final determination that we violated applicable laws could, among other things, result in our debarment from future federal government contracts.

In February 2008, the DOJ advised us that the EPA has requested that the DOJ initiate a lawsuit against usNuPOP for (a) failing to prepare adequate Facility Response Plans, as required by Section 311(j)(5) of the Clean Water Act, 33 U.S.C. §1321(j), for certain of our pipeline terminals located in Region VII, by August 30, 1994, and (b) maintaining Spill Prevention, Control and Countermeasure (SPCC) Plans at the terminal that deviate from the SPCC regulations, 40 C.F.R. §112.3. A Facility Response Plan is a plan for responding to a worst case discharge, and to a substantial threat of such a discharge, of oil or hazardous substances. The SPCC rule requires specific facilities to prepare, amend and implement plans to prevent, prepare and respond to oil discharges to navigable waters and adjoining shorelines. We are currently in settlement negotiations with the DOJ to resolve these matters.

In addition, our wholly owned subsidiary, Shore Terminals LLC (Shore) owns a refined product terminal in Portland, Oregon located adjacent to the Portland Harbor. The EPA has classified portions of the Portland Harbor, including the portion adjacent to our terminal, as a federal “Superfund” site due to sediment contamination (the Portland Harbor Site). Portland Harbor is contaminated with metals (such as mercury), pesticides, herbicides, polynuclear aromatic hydrocarbons, polychlorinated byphenyls, semi-volatile organics and dioxin/furans. Shore and more than 80 other parties have received a “General Notice” of potential liability from the EPA relating to the Portland Harbor Site. The letter advised Shore that it may be liable for the costs of investigation and remediation (which liability may be joint and several with other potentially responsible parties), as well as for natural resource damages resulting from releases of hazardous substances to the Portland Harbor Site. We have agreed to work with more than 65 other potentially responsible parties to attempt to negotiate an agreed method of allocating costs associated with the cleanup. The precise nature and extent of any clean-up of the Portland Harbor Site, the parties to be involved, the process to be followed for any clean-up and the allocation of any costs for the clean-up among responsible parties have not yet been determined. It is unclear to what extent, if any, we will be liable for environmental costs or damages associated with the Portland Harbor Site. It is also unclear to what extent natural resource damage claims or third party contribution or damage claims will be asserted against Shore.

In September 2009, an administrative complaint was filed by the EPA in Region III against NuStar Terminals Operations Partnership, L.P. (NTOP) and NuStar Terminals Services, Inc. (NTS). The administrative complaint alleges the certain violations occurred at NTOP’s Baltimore, Maryland terminal facility. The alleged violations include failure to comply with certain discharge limitations and certain monitoring and reporting obligations, as required by Section 301 of the Clean Water Act, 33 U.S.C. § 1311. The administrative complaint further alleges that NTOP and NTS violated certain provisions of the Code of Maryland Regulations (COMAR), which the EPA is entitled to enforce on behalf of the State of Maryland pursuant to Section 3008(a) of the Resource Conservation and Recovery Act, 42 U.S.C. § 6928(a). The total civil penalty sought by the EPA is $199,400. We have agreed to mediate this dispute.

We are also a party to additional claims and legal proceedings arising in the ordinary course of business. Due to the inherent uncertainty of litigation, there can be no assurance that the resolution of any particular claim or proceeding would not have a material adverse effect on our results of operations, financial position or liquidity. It is possible that if one or more of the matters described in Item 3. were decided against us, the effects could be material to our results of operations in the period in which we would be required to record or adjust the related liability and could also be material to our cash flows in the periods we would be required to pay such liability.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

No matters were submitted to a vote of the unitholders, through solicitation of proxies or otherwise, during the fourth quarter of the year ended December 31, 2008.2009

PART II

ITEM 5. MARKET FOR REGISTRANT’S COMMON UNITS, RELATED UNITHOLDER MATTERS AND ISSUER PURCHASES OF COMMON UNITS

ITEM 5.MARKET FOR REGISTRANT’S COMMON UNITS, RELATED UNITHOLDER MATTERS AND ISSUER PURCHASES OF COMMON UNITS

Market Information, Holders and Distributions

Our common units are listed and traded on the New York Stock Exchange under the symbol “NS.” At the close of business on February 5, 2009,2010, we had 857792 holders of record of our common units. The high and low sales prices (composite transactions) by quarter for the years ended December 31, 20082009 and 20072008 were as follows:

 

  

Price Range of

Common Unit

  

Price Range of

Common Unit

   
  

High

    

Low

  

High

     

Low

  

Year 2009

        

4th Quarter

  $ 57.34    $ 50.54  

3rd Quarter

   57.20     50.51  

2nd Quarter

   57.68     45.51  

1st Quarter

   50.88     40.45  

Year 2008

                

4th Quarter

  $  46.89    $  27.00  $46.89    $27.00  

3rd Quarter

   50.45     40.00   50.45     40.00  

2nd Quarter

   54.90     47.00   54.90     47.00  

1st Quarter

   57.15     47.76   57.15     47.76  

Year 2007

        

4th Quarter

  $  63.89    $  51.80

3rd Quarter

   70.09     52.31

2nd Quarter

   71.50     61.83

1st Quarter

   68.00     54.11

The cash distributions applicable to each of the quarters in the years ended December 31, 20082009 and 20072008 were as follows:

 

  

Record Date

  

Payment Date

  

Amount
Per Unit

  

Record Date

  

Payment Date

  

Amount
Per Unit

   

Year 2009

        

4th Quarter

  February 5, 2010  February 12, 2010  $1.0650  

3rd Quarter

  November 5, 2009  November 12, 2009   1.0650  

2nd Quarter

  August 6, 2009  August 13, 2009   1.0575  

1st Quarter

  May 8, 2009  May 15, 2009   1.0575  

Year 2008

                 

4th Quarter

  February 5, 2009  February 12, 2009  $ 1.0575  February 5, 2009  February 12, 2009  $1.0575  

3rd Quarter

  November 5, 2008  November 12, 2008   1.0575  November 5, 2008  November 12, 2008   1.0575  

2nd Quarter

  August 6, 2008  August 13, 2008   0.9850  August 6, 2008  August 13, 2008   0.9850  

1st Quarter

  May 7, 2008  May 14, 2008   0.9850  May 7, 2008  May 14, 2008   0.9850  

Year 2007

         

4th Quarter

  February 7, 2008  February 14, 2008  $0.9850

3rd Quarter

  November 8, 2007  November 14, 2007   0.9850

2nd Quarter

  August 7, 2007  August 14, 2007   0.9500

1st Quarter

  May 7, 2007  May 14, 2007   0.9150

Our general partner is entitled to incentive distributions if the amount that we distribute with respect to any quarter exceeds specified target levels shown below:

 

   

Percentage of Distribution

  
    Quarterly Distribution Amount per Unit  

Unitholders

 

General Partner

 

Up to $0.60

  98%    2% 

Above $0.60 up to $0.66

  90% 10% 

Above $0.66

  75% 25% 

Our general partner’s incentive distributions for the years ended December 31, 2009 and 2008 and 2007 totaled $25.3$28.7 million and $18.4$25.3 million, respectively. The general partner’s share of our distributions for the years ended December 31, 2009 and 2008 was 12.6% and 2007 was 12.0% and 11.0%, respectively, due to the impact of the incentive distributions.

ITEM 6. SELECTED FINANCIAL DATA

The following table contains selected financial data derived from our audited financial statements.

 

   

Year Ended December 31,

   

2008 (a)

  

2007

  

2006

  

2005 (b)

  

2004

   (Thousands of Dollars, Except Per Unit Data)

Statement of Income Data:

          

Revenues

  $4,828,770  $1,475,014  $1,137,261  $659,557  $220,792

Operating income

   310,073   192,599   212,899   152,952   97,268

Income from continuing operations

   254,018   150,298   149,906   107,675   78,418

Income from continuing operations per unit applicable to limited partners (c)

   4.22   2.74   2.84   2.76   3.15

Cash distributions per unit applicable to limited partners

   4.085   3.835   3.600   3.365   3.20

  

Year Ended December 31,

2009

  

2008 (a)

  

2007

  

2006

  

2005

(Thousands of Dollars, Except Per Unit Data)

Statement of Income Data:

          

Revenues

  $ 3,855,871  $ 4,828,770  $ 1,475,014  $ 1,137,261  $659,557

Operating income

   273,316   310,073   192,599   212,899   152,952

Income from continuing operations

   224,875   254,018   150,298   149,906   107,675

Income from continuing operations per unit applicable to limited partners (b)

   3.47   4.22   2.73   2.82   2.76

Cash distributions per unit applicable to limited partners

   4.245   4.085   3.835   3.600   3.365
  

December 31,

  

December 31,

  

2009

  

2008 (a)

  

2007

  

2006

  

2005

  

2008 (a)

  

2007

  

2006

  

2005 (b)

  

2004

  (Thousands of Dollars)
  (Thousands of Dollars)

Balance Sheet Data:

                    

Property, plant and equipment, net

  $2,941,824  $2,492,086  $2,345,135  $2,160,213  $784,999  $3,028,196  $2,941,824  $2,492,086  $2,345,135  $2,160,213

Total assets

   4,459,597   3,783,087   3,494,208   3,366,992   857,507   4,774,673   4,459,597   3,783,087   3,494,208   3,366,992

Long-term debt (less current portion)

   1,872,015   1,445,626   1,353,720   1,169,659   384,171   1,828,993   1,872,015   1,445,626   1,353,720   1,169,659

Partners’ equity

   2,206,997   1,994,832   1,875,681   1,900,779   438,311   2,484,968   2,206,997   1,994,832   1,875,681   1,900,779

 

(a)

The significant increase in revenues, operating income, income from continuing operations and balance sheet data are primarily due to our acquisition of the East Coast Asphalt Operations.

(b)

The significant increase in revenues, operating income, income from continuing operations and balance sheet data are primarily due to the Kaneb Acquisition.

acquisition of our asphalt operations in March 2008.

(c)(b)

Income from continuing operationsIn 2008, the Financial Accounting Standards Board provided additional guidance regarding the application of the two-class method to calculate earnings per unit applicable tofor master limited partners is computed by dividing income from continuing operations applicable to limited partners, after deduction of the general partner’s 2% interest and incentive distributions, by the weighted average number of limited partnership units outstanding for each class of unitholder. Basic and dilutedpartnerships, which was effective January 1, 2009. As a result, income from continuing operations per unit applicable to limited partners isfor the same because we have no potentially dilutive securities outstanding.

years ended December 31, 2007 and 2006 changed from $2.74 and $2.84, respectively, previously reported.

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

ITEM 7.MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following review of our results of operations and financial condition should be read in conjunction with Items 1., 1A. and 2. “Business, Risk Factors and Properties” and Item 8. “Financial Statements and Supplementary Data” included in this report.

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This Form 10-K contains certain estimates, predictions, projections, assumptions and other forward-looking statements that involve various risks and uncertainties. While these forward-looking statements, and any assumptions upon which they are based, are made in good faith and reflect our current judgment regarding the direction of our business, actual results will almost always vary, sometimes materially, from any estimates, predictions, projections, assumptions or other future performance suggested in this report. These forward-looking statements can generally be identified by the words “anticipates,” “believes,” “expects,” “plans,” “intends,” “estimates,” “forecasts,” “budgets,” "projects,“projects,” “will,” “could,” “should,” “may” and similar expressions. These statements reflect our current views with regard to future events and are subject to various risks, uncertainties and assumptions. Please read Item 1A. “Risk Factors” for a discussion of certain of those risks.

If one or more of these risks or uncertainties materialize, or if the underlying assumptions prove incorrect, our actual results may vary materially from those described in any forward-looking statement. Other unknown or unpredictable factors could also have material adverse effects on our future results. Readers are cautioned not to place undue reliance on this forward-looking information, which is as of the date of the Form 10-K. We do not intend to update these statements unless it is required by the securities laws to do so, and we undertake no obligation to publicly release the result of any revisions to any such forward-looking statements that may be made to reflect events or circumstances after the date of this report or to reflect the occurrence of unanticipated events.

OVERVIEW

NuStar Energy L.P. (NuStar Energy) (NYSE: NS) is engaged in the terminalling and storage of petroleum products, the transportation of petroleum products and anhydrous ammonia, and asphalt and fuels marketing. Unless otherwise indicated, the terms “NuStar Energy L.P.,” “the Partnership,” “we,” “our” and “us” are used in this report to refer to NuStar Energy, to one or more of our consolidated subsidiaries or to all of them taken as a whole. NuStar GP Holdings, LLC (NuStar GP Holdings) (NYSE: NSH) wholly owns our general partner, Riverwalk Logistics, L.P., and owns a 20.5%an 18.7% total interest in us.us as of December 31, 2009. Our Management’s Discussion and Analysis of Financial Condition and Results of Operations is presented in five sections:

 

Overview

Results of Operations

Outlook

Liquidity and Capital Resources

Related Party Transactions

Critical Accounting Policies

Recent DevelopmentsAcquisition

On March 20, 2008, we acquired CITGO Asphalt Refining Company’s asphalt operations and assets (the East Coast Asphalt Operations) for approximately $838.5 million. The East Coast Asphalt Operations include, which included a 74,000 barrels-per-day (BPD)barrels per day asphalt refinery in Paulsboro, New Jersey, a 30,000 BPDbarrels per day asphalt refinery in Savannah, Georgia and three asphalt terminals. The facilities locatedterminals in Paulsboro, New Jersey, Savannah, Georgia and Wilmington, North Carolina have storage capacities of 3.5 million barrels, 1.2 million barrels and 0.2 million barrels, respectively. We funded the acquisition with proceeds from our common unit offerings in November 2007 and April 2008, related contributions from our general partner to maintain its 2% interest, proceeds from our issuance of $350.0 million of senior notes and borrowings under our revolving credit agreement. See Liquidity and Capital Resources below for a discussion of our common unit offerings, issuance of senior notes and our revolving credit agreement.

On December 1, 2008, we agreed to dispose of our interest in the Skelly-Belvieu Pipeline Company, LLC, which owns a liquefied petroleum gas pipeline in Texas, to Enterprise Products Operating LLC. We received proceeds of $36.0 million and recognized a gain of $18.9 million on this sale.

During 2008, we sold four of our refined product terminals in Westwego, Louisiana, Tucson, Arizona, Milwaukee, Wisconsin and Reno, Nevada with an aggregate storage capacity of approximately 1.3 million barrels for total proceeds of approximately $9.9 million.Carolina.

Operations

We conduct our operations through our wholly owned subsidiaries, primarily NuStar Logistics, L.P. (NuStar Logistics) and NuStar Pipeline Operating Partnership L.P. (NuPOP)

Beginning in the second quarter of 2008, we revised the manner in which we internally evaluate our segment performance. Our operations are divided into three reportable business segments: storage, transportation, and made certain organizational changes. As a result, we have changed the way we report our segmental results. All product sales and related costs, including those associated with the East Coast Asphalt Operations, are included in the asphalt and fuels marketing segment. Also, the refined product terminals and crude oil storage tanks segments have been combined into the storage segment and the refined products pipelines and crude oil pipelines have been combined into the transportation segment. Previous periods have been restated to conform to this presentation.marketing. For a more detailed description of our segments, please refer to Segments under Item 1. “Business.”

StorageStorage..    We own refined product terminals in the United States, the Netherland Antilles, Canada, Mexico, the Netherlands and the United Kingdom providing approximately 61.2 million barrels of storage capacity and one crude oil storage facility providing approximately 4.866.2 million barrels of storage capacity. We also own 60 crude oil and intermediate feedstock storage tanks and related assets that store and deliver crude oil and intermediate feedstocksprovide an aggregate 12.5 million barrels of storage capacity to Valero Energy’s refineries in Benicia, California Corpus Christi, Texas and Texas City, Texas.

TransportationTransportation..    We own common carrier refined product pipelines in Texas, Oklahoma, Colorado, New Mexico, Kansas, Nebraska, Iowa, South Dakota, North Dakota and Minnesota covering approximately 5,6795,605 miles, consisting of the Central West System, the East Pipeline and the North Pipeline. In addition, we own a 2,000 mile anhydrous ammonia pipeline located in Louisiana, Arkansas, Missouri, Illinois, Indiana, Iowa and Nebraska. We also own 812 miles of crude oil pipelines in Texas, Oklahoma, Kansas, Colorado and Illinois, as well as associated crude oil storage facilities providing storage capacity of 1.9 million barrels in Texas and Oklahoma that are located along the crude oil pipelines.

Asphalt and Fuels MarketingMarketing..    Our asphalt and fuels marketing segment includes our asphalt refining operations and our fuels marketing operations. We refine crude oil to produce asphalt and certain other refined products from our asphalt operations. We own two asphalt refineries with a combined throughput capacity of 104,000 barrels per day and related terminal facilities providing storage capacity of 5.0 million barrels. Additionally, as part of our fuels marketing operations, we purchase gasoline and other refined petroleum products for resale. The results of operations for the asphalt and fuels marketing segment depend largely on the gross margin between our cost and the sales price of the products we market. Therefore, the results of operations for this segment are more sensitive to changes in commodity prices compared to the operations of the storage and transportation segments.

We enter into derivative contracts to mitigate the effect of commodity price fluctuations. We record the fair value of our derivative instruments in our consolidated balance sheet, with the change in fair value recorded in earnings. The derivative instruments we use consist primarily of futures contracts and swaps traded on the NYMEX for the purposes of hedging the outright price risk of our physical inventory. Not all of our derivative instruments qualify for hedge accounting treatment under United States generally accepted accounting principles. In such cases, we record the changes in the fair values of thethese derivative instrument, which are includedinstruments in cost of product sales,sales. The changes in the fair values of these derivative instruments generally are offset, at least partially, by changes in the values of the hedged physical inventory. However, we do not recognize those changes in the market fluctuations invalue of the hedged inventory are not recognized until the physical sale of such inventory takes place, unless the market price of inventory falls below our cost. If the cost of our inventory exceeds the realizable value, we reduce the value of our inventory to the realizable value.place. Therefore, our resultsearnings for a period may include the gain or loss related to the derivative instrumentinstruments without including the offsetting effect of the hedged physical inventory,item, which could result in greater earnings volatility.

In addition, we value our inventory at the lower of cost or market. If changes in commodity prices result in market prices below the cost of our inventory, we may be required to reduce the value of our inventory to market.

Demand for certain of the products we market fluctuates seasonally. For example, demand for gasoline and asphalt is typically higher in the summer months than the winter months, whereas demand for heating oil is higher in the winter months than the summer months. Prices for these commodities generally are highest during those times of higher demand. In addition to purchasing inventory for immediate resale, we have and expect to continue to employ a strategy of purchasing inventory during times of lower demand and lower prices and storing that inventory until it can be sold at higher prices. We expect that our overall level of working capital will continue to increase to support the operations of the asphalt and fuels marketing segment. Additionally, the level of working capital employed by the asphalt and fuels

marketing segment will likely fluctuate seasonally. The absolute increase in the level of working capital, as well as the seasonal fluctuations, may require us to borrow additional amounts or utilize other sources of liquidity.

The following factors affect the results of our operations:

 

company-specific factors, such as integrity issues and maintenance requirements that impact the throughput rates of our assets;

seasonal factors that affect the demand for products transported by and/or stored in our assets and the demand for products we sell, particularly asphalt;

industry factors, such as changes in the prices of petroleum products that affect demand and operations of our competitors;

factors such as commodity price volatility and market structure that impact our asphalt and fuels marketing segment; and

other factors, such as refinery utilization rates and maintenance turnaround schedules, that impact our refineries as well as the operations of refineries served by our storage and transportation assets.

RESULTS OF OPERATIONS

Year Ended December 31, 20082009 Compared to Year Ended December 31, 20072008

Financial Highlights

(Thousands of Dollars, Except Unit and Per Unit Data)

 

 

Year Ended December 31,

   
  

Year Ended December 31,

      2009   2008   Change 
  

2008

 

2007

 

Change

           

Statement of Income Data:

           

Revenues:

            

Service revenues

  $740,630  $696,623  $44,007  $  745,349    $  740,630    $  4,719  

Product sales

   4,088,140   778,391   3,309,749   3,110,522     4,088,140     (977,618
                        

Total revenues

   4,828,770   1,475,014   3,353,756   3,855,871     4,828,770     (972,899
                        

Costs and expenses:

            

Cost of product sales

   3,864,310   742,972   3,121,338   2,883,187     3,864,310     (981,123

Operating expenses

   442,248   357,235   85,013   458,892     442,248     16,644  

General and administrative expenses

   76,430   67,915   8,515   94,733     76,430     18,303  

Depreciation and amortization expense

   135,709   114,293   21,416   145,743     135,709     10,034  
                        

Total costs and expenses

   4,518,697   1,282,415   3,236,282   3,582,555     4,518,697     (936,142
                        

Operating income

   310,073   192,599   117,474   273,316     310,073     (36,757

Equity earnings from joint ventures

   8,030   6,833   1,197   9,615     8,030     1,585  

Interest expense, net

   (90,818)  (76,516)  (14,302)  (79,384   (90,818   11,434  

Other income, net

   37,739   38,830   (1,091)  31,859     37,739     (5,880
                        

Income before income tax expense

   265,024   161,746   103,278   235,406     265,024     (29,618

Income tax expense

   11,006   11,448   (442)  10,531     11,006     (475
                        

Net income

   254,018   150,298   103,720  $  224,875    $  254,018    $  (29,143

Less net income applicable to general partner

   (29,350)  (21,063)  (8,287)
                        

Net income applicable to limited partners

  $224,668  $129,235  $95,433 
          

Net income per unit applicable to limited partners

  $4.22  $2.74  $1.48  $  3.47    $  4.22    $  (0.75
                        

Weighted average number of basic units outstanding

   53,182,741   47,158,790   6,023,951 

Weighted average limited partner units outstanding

  55,232,467     53,182,741     2,049,726  
              

Annual Highlights

Net income increased $103.7decreased $29.1 million for the year ended December 31, 2008,2009, compared to the year ended December 31, 2007,2008, primarily due to an increase in general and administrative expenses and a decrease in segment operating income,income. This was partially offset by increasesa decrease in interest expense, net and general and administrative expenses. expense.

Segment operating income increased $126.0decreased $17.1 million for the year ended December 31, 2008,2009, compared to the year ended December 31, 2007,2008, primarily due to a $91.4$51.9 million increasedecrease in operating income for the asphalt and fuels marketing segment, which was mainly resulting from robust sales volumes and strong product marginsdue to higher operating expenses associated with our asphalt operations. The decrease in operating income from our East Coast Asphalt Operations during the third quarter. Operatingasphalt and fuels marketing segment was partially offset by increased operating income increased forfrom our storage and transportation segments $26.4 million and $8.6 million, respectively, primarily due to increased throughputs and earnings in 2008 compared to 2007 due to a fire at the Valero Energy McKee refinery in February 2007, which shut down the refinery until mid-April 2007 and negatively impacted our transportation and storage segments during the year ended December 31, 2007. Operating income for the storage segment also improved due to the leasing of additional storage capacity to customers from completed tank expansion projects.

However, our earnings were negatively impacted by a hedging loss of approximately $61.0 million in the second quarter of 2008. Concurrent with the acquisition of the East Coast Asphalt Operations, we entered into certain derivative contracts intended to hedge our exposure to price fluctuations for approximately 30% of the inventory acquired. We entered into these contracts to protect the value of our acquired inventories in the case crude oil prices declined. However, the price of crude oil increased dramatically from the date we entered into the hedges until May 2008, at whichsegments.

time we terminated the contracts prior to their expiration. Currently, we do not have any derivative contracts related to inventories of the East Coast Asphalt Operations, and we manage our commodity risk by managing those physical inventory volumes. We continue to monitor our exposure to commodity prices and may, if conditions warrant, hedge the inventories of the East Coast Asphalt Operations in the future.

Segment Operating Highlights

(Thousands of Dollars, Except Barrel/Day Information)

 

 

Year Ended December 31,

   
  Year Ended December 31,      2009   2008   Change 
  

2008

 

2007

 

Change

           

Storage:

            

Throughput (barrels/day)(a)

   742,599   800,332   (57,733)  667,169     742,599     (75,430

Throughput revenues

  $90,918  $96,372  $(5,454) $  78,353    $  90,918    $  (12,565

Storage lease revenues

   363,171   314,255   48,916   409,219     363,171     46,048  
                        

Total revenues

   454,089   410,627   43,462   487,572     454,089     33,483  

Operating expenses

   246,304   233,675   12,629   245,439     246,304     (865

Depreciation and amortization expense

   66,706   62,317   4,389   70,888     66,706     4,182  
                        

Segment operating income

  $141,079  $114,635  $26,444  $  171,245    $  141,079    $  30,166  
                        

Transportation:

            

Refined products pipelines throughput (barrels/day)

   673,687   678,573   (4,886)  573,778     673,687     (99,909

Crude oil pipelines throughput (barrels/day)

   392,110   377,640   14,470   351,888     392,110     (40,222
                        

Total throughput (barrels/day)

   1,065,797   1,056,213   9,584   925,666     1,065,797     (140,131

Throughput revenues

  $317,778  $296,796  $20,982  $  302,070    $  317,778    $  (15,708

Operating expenses

   131,943   120,342   11,601   111,673     131,943     (20,270

Depreciation and amortization expense

   50,749   49,946   803   50,528     50,749     (221
                        

Segment operating income

  $135,086  $126,508  $8,578  $  139,869    $  135,086    $  4,783  
                        

Asphalt and Fuels Marketing:

            

Product sales

  $4,088,169  $778,391  $3,309,778  $  3,110,522    $  4,088,169    $  (977,647

Cost of product sales

   3,880,796   750,120   3,130,676   2,899,457     3,880,796     (981,339

Operating expenses

   80,133   6,737   73,396   130,973     80,133     50,840  

Depreciation and amortization expense

   14,734   423   14,311   19,463     14,734     4,729  
                        

Segment operating income

  $112,506  $21,111  $91,395  $  60,629    $  112,506    $  (51,877
                        

Consolidation and Intersegment Eliminations:

            

Revenues

  $(31,266) $(10,800) $(20,466) $  (44,293  $  (31,266  $  (13,027

Cost of product sales

   (16,486)  (7,148)  (9,338)  (16,270   (16,486   216  

Operating expenses

   (16,132)  (3,519)  (12,613)  (29,193   (16,132   (13,061

Depreciation and amortization expense

   3,520   1,607   1,913 
                        

Total

  $(2,168) $(1,740) $(428) $  1,170    $  1,352    $  (182
              
          

Consolidated Information:

            

Revenues

  $4,828,770  $1,475,014  $3,353,756  $  3,855,871    $  4,828,770    $  (972,899

Cost of product sales

   3,864,310   742,972   3,121,338   2,883,187     3,864,310     (981,123

Operating expenses

   442,248   357,235   85,013   458,892     442,248     16,644  

Depreciation and amortization expense

   135,709   114,293   21,416   140,879     132,189     8,690  
                        

Segment operating income

   386,503   260,514   125,989   372,913     390,023     (17,110

General and administrative expenses

   76,430   67,915   8,515   94,733     76,430     18,303  

Other depreciation and amortization expense

  4,864     3,520     1,344  
                        

Consolidated operating income

  $310,073  $192,599  $117,474  $  273,316    $  310,073    $  (36,757
                        

 

(a)

Excludes throughputs related to storage lease revenues.

Storage

Throughputs decreased 57,73375,430 barrels per day for the year ended December 31, 2009, compared to the year ended December 31, 2008, mainly due to the conversion of some throughput-based contracts to lease-based contracts in January 2009. Throughputs for these terminals are no longer reported, and throughput revenues associated with these terminals are reported under storage lease revenues. In addition, throughputs decreased $5.5due to turnarounds in the first quarter of 2009 at a refinery served by our Texas City crude oil storage tanks and a turnaround at the McKee refinery in May 2009.

Total revenues increased by $33.5 million for the year ended December 31, 2008,2009, compared to the year ended December 31, 2007,2008, primarily due to a change in our Corpus Christi (North Beach) crude oilhigher storage tank agreement from a throughput fee agreement to a storage lease agreement effective January 1, 2008. Partially offsetting these decreases were higher throughputs and revenues at terminals serving the McKee refinery mainly due to lower throughputs and revenues in 2007 resulting from the impact of the Valero Energy McKee refinery fire, which shut down the refinery until mid-April 2007.associated with:

Storage lease revenues increased by $48.9 million for the year ended December 31, 2008, compared to the year ended December 31, 2007, primarily due to:

an increase of $20.7$20.0 million due to completed tank expansion projects at our St. Eustatius, Amsterdam, St. James, Vancouver, PortlandTexas City and Jacksonville terminals;

an increase of $9.9$6.7 million mainly due to increasedat certain of our domestic terminals resulting from an increase in product throughput and new customer contracts at our UK terminal facilities, increased throughputs and productassociated handling revenues at our Amsterdam facility, as well as the effect of foreign exchange rates at our UK and Amsterdam facilities;fees;

an increase of $9.4$4.3 million mainly at our west coast terminals primarily due to a change in our Corpus Christi (North Beach) crude oilhigher negotiated storage tank agreement from a throughput fee agreement to a storage lease agreement effective January 1, 2008;rates; and

an increase of $2.8$3.1 million at our asphalt terminals primarily due to new storage-based contracts with the asphalt and fuels marketing segment.

These increases were partially offset by a decrease of $3.5 million due to the sales of our acquisition of the Wilmington asphalt terminal;Westwego, Louisiana, Reno, Nevada and Milwaukee, Wisconsin terminals in December 2008.

an increase of $2.7 million at our Point Tupper facility due toDepreciation and amortization expense increased throughputs, handling charges, reimbursable revenues and dock activity.

Operating expenses increased $12.6$4.2 million for the year ended December 31, 2008,2009, compared to the year ended December 31, 2007, primarily due to:

higher salaries and wages of $4.0 million resulting primarily from increased headcount and foreign currency fluctuations;

increased power costs of $3.3 million mainly due to increased fuel consumption at our St. Eustatius and Pt. Tupper facilities, increased costs at our Amsterdam facility and our acquisition of the Wilmington asphalt terminal;

increased costs of $2.9 million primarily at our Texas City terminal related to Hurricane Ike, which made landfall in September 2008; and

an increase of $2.5 million in environmental expense related to an ongoing investigation at one of our refined product terminals.

Depreciation and amortization expense increased $4.4 million for the year ended December 31, 2008, compared to the year ended December 31, 2007, primarily due to the completion of various terminal expansion projects.

Transportation

Throughputs increased 9,584decreased 140,131 barrels per day and revenues increased $21.0decreased $15.7 million for the year ended December 31, 2008,2009, compared to the year ended December 31, 2007,2008, primarily due to increasedto:

lower throughputs of 42,246 barrels per day and a decrease in revenues of $21.5$7.0 million aton our pipelines serving the McKee refinery. 2007 revenues were adversely affected by the impact of the Valero Energy McKee refinery fire. 2008 revenues also increasedprimarily due to higher tariffsa turnaround in May 2009 and lower overall demand resulting from the economic downturn. In addition, throughputs and revenues decreased due to a shipper using alternate pipelines in the third and fourth quarters of 2009, and a shipper acquiring our joint venture partner’s interest in a pipeline and shipping product on all of the refined product and crude oil pipelines as the annual index adjustment was effective July 1, 2008.

its purchased space rather than our space. These increasesdecreases were partially offset by decreasedhigher revenue related to a new shipper with a minimum throughput agreement that began in late 2008;

a decrease in throughputs of 6,568 barrels per day and a decrease in revenues of $4.4 million on the Ammonia Pipeline due to high inventory levels of ammonia in the Midwest that carried over from the fall of 2008 and unseasonably wet and cold weather in the first half of 2009;

a decrease in throughputs of 28,132 barrels per day and a decrease in revenues of $1.7 million due to the sale of the Ardmore-Wynnewood pipeline in June 2009;

a decrease in throughputs of 14,651 barrels per day and a decrease in revenues of $1.0 million on our Houston pipeline in 2008 as more product was exported by one of our customers instead of shipped inland through our pipeline. In addition,pipelines serving the Wynnewood pipeline experienced lower revenuesArdmore refinery due to decreased long haul deliveriesoperational issues at the refinery during the second and third quarters of 2009 and a refinery shut down in 2008. Also,the third quarter of 2009 following a lightning strike;

a decrease in throughputs decreased mainlyof 15,615 barrels per day on our pipelines serving the Three Rivers refinery due to a scheduled turnaround during the third quarter of 2009 and reduced crude supply interruptions and other operational issues at a refinery served by the Wynnewood pipeline. Reduced demand in 2008run rates resulting from the economic downturn; and

a prolonged winter and floodingdecrease of 11,338 barrels per day due to the sale of the Skelly-Belvieu pipeline in December 2008.

The tariff increase of 7.6% that became effective July 1, 2009 partially offset declines in revenues from the Midwest and higher commodity prices, along with record throughputs in 2007, contributed to lower throughputs on our East Pipeline.throughputs.

Operating expenses for this segment increased $11.6decreased $20.3 million for the year ended December 31, 2008,2009, compared to the year ended December 31, 2007,2008, primarily due to:

a decrease of $9.5 million due to increased power costs as a result of the increasereduction in throughputs on pipelines serving the McKee refinery, higher natural gasour product imbalance liability resulting from lower commodity prices and the impact of significantly lower product prices onassociated with our product imbalances on the East Pipeline. Also, salaries and wages and internal overhead expense increased, both due primarily to increased headcount. These increases werePipeline, partially offset by decreaseda hedging loss;

a decrease of $8.6 million in power costs resulting from lower throughputs and lower natural gas prices; and

a decrease of $1.5 million in maintenance and environmental expenses.contractor expenses on certain of the refined product pipelines resulting from fewer repair projects in 2009.

Asphalt and Fuels Marketing

Sales and cost of product sales increased $3,309.8decreased $977.6 million and $3,130.7$981.3 million, respectively, duringresulting in an increase in total gross margin of $3.7 million for the year ended December 31, 2008,2009, compared to the year ended December 31, 2007, mainly2008 due to:to the following:

an increase of $2,496.3$6.7 million and $2,347.5 million in sales and cost of product sales, respectively, from our acquisitionasphalt operations mainly due to higher volumes sold and a slightly higher gross margin per barrel of the East Coast Asphalt Operations in March 2008. Cost of product sales$6.37 compared to $6.22. The gross margin per barrel for the year ended December 31, 2008 includes the negative impact of a $61.0 million hedging loss discussed in the Annual Highlights above;loss; and

an increasea decrease of $585.7$3.0 million and $576.0 million in sales and cost of product sales, respectively, associated withrelated to our fuels marketing operations that began in the second quarter of 2007;mainly due to higher hedging losses, which were partially offset by increased volumes from entering new markets and

an increase of $233.0 million and $210.8 million for sales and cost of product sales, respectively, associated with our increased bunker fuel operations due to an increase in the market price per metric ton at our St. Eustatius facility and increased sales at our Point Tupper facility, which resumed the sale of bunker fuel in the second quarter of 2008. Cost of sales includes a hedge gain of $28.1 million primarily associated with bunker fuel sales at our Point Tupper facility.sales.

Operating expenses increased by $73.4$50.8 million for the year ended December 31, 2008,2009, compared to the year ended December 31, 2007,2008, primarily due to:

an increase of $58.3$35.8 million from ourmainly due to a full year of expenses related to the acquisition of the East Coast Asphalt Operationsour asphalt operations, which occurred in March 2008;2008, the amortization of deferred maintenance costs, higher idle capacity costs and increased asphalt terminal rentals;

an increase of $13.9$5.9 million related to marine expenses mainly due to increased tug and barge rental costs as agreements forassociated with new tugs and bargesvessels being received at our St. Eustatius were effective January 1, 2008.facility throughout 2008 and 2009 and the addition of bunkering activities at certain domestic terminals; and

an increase of $4.4 million due to increased storage costs resulting from additional tank rentals.

Depreciation and amortization expense increased $14.3$4.7 million for the year ended December 31, 2008,2009, compared to the year ended December 31, 2007,2008, due to our acquisition of the East Coast Asphalt Operations in March 2008.

Consolidation and Intersegment Eliminations

Revenue, cost of product sales and operating expense eliminations primarily relate to storage and transportation fees charged to the asphalt and fuels marketing segment by the transportation and storage segments. In 2009, the asphalt and fuels marketing segment utilized more terminal capacity from our storage segment, resulting in higher revenue and operating expense eliminations.

General

General and administrative expenses increased by $18.3 million for the year ended December 31, 2009, compared to the year ended December 31, 2008. This increase was primarily due to compensation expense associated with our long-term incentive plans resulting from an increase in our unit price during the year ended December 31, 2009 compared to a decrease in our unit price during the year ended December 31, 2008. In addition, general and administrative expenses increased due to higher external legal costs and other professional fees.

Interest expense, net decreased by $11.4 million for the year ended December 31, 2009, compared to the year ended December 31, 2008, primarily due to decreases in interest rates, including the variable interest rate paid on our interest rate swaps. These decreases in interest expense were partially offset by increased interest expense from the issuance of $350.0 million of 7.65% senior notes in April 2008 and lower capitalized interest.

Other income, net consisted of the following:

    

Year Ended December 31,

    

2009

  

2008

   (Thousands of Dollars)

Gain from sale or disposition of assets

  $   21,320   $   26,456

Gain from insurance proceeds

    9,382     3,504

Foreign exchange (losses) gains

    (5,118   5,888

Other

    6,275     1,891
          

Other income, net

  $   31,859   $   37,739
          

See Note 18 of Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplemental Data” for further information regarding the other components of other income.

Year Ended December 31, 2008 Compared to Year Ended December 31, 2007

Financial Highlights

(Thousands of Dollars, Except Unit and Per Unit Data)

    

Year Ended December 31,

     

Change

 
    

2008

    

2007

    

Statement of Income Data:

       

Revenues:

       

Service revenue

 $ 740,630   $ 696,623   $  44,007  

Product sales

  4,088,140    778,391     3,309,749  
             

Total revenues

  4,828,770    1,475,014     3,353,756  
             

Costs and expenses:

       

Cost of product sales

  3,864,310    742,972     3,121,338  

Operating expenses

  442,248    357,235     85,013  

General and administrative expenses

  76,430    67,915     8,515  

Depreciation and amortization expense

  135,709    114,293     21,416  
             

Total costs and expenses

  4,518,697    1,282,415     3,236,282  
             

Operating income

  310,073    192,599     117,474  

Equity earnings from joint ventures

  8,030    6,833     1,197  

Interest expense, net

  (90,818  (76,516   (14,302

Other income , net

  37,739    38,830     (1,091
             

Income before income tax expense

  265,024    161,746     103,278  

Income tax expense

  11,006    11,448     (442
             

Net income

 $ 254,018   $ 150,298   $  103,720  
             

Net income per unit applicable to limited partners

 $ 4.22   $ 2.73   $  1.49  
             

Weighted average limited partner units outstanding

  53,182,741    47,158,790     6,023,951  
             

Annual Highlights

Net income increased $103.7 million for the year ended December 31, 2008, compared to the year ended December 31, 2007, primarily due to an increase in segment operating income, partially offset by increases in interest expense, net and general and administrative expenses. Segment operating income increased $127.9 million for the year ended December 31, 2008, compared to the year ended December 31, 2007, primarily due to a $91.4 million increase in operating income for the asphalt and fuels marketing segment, mainly resulting from robust sales volumes and strong gross margins from our East Coast Asphalt Operations during the third quarter. Operating income increased for our storage and transportation segments $26.4 million and $8.6 million, respectively, primarily due to increased throughputs and earnings in 2008 compared to 2007 due to a fire at the Valero Energy McKee refinery in February 2007, which shut down the refinery until mid-April 2007 and negatively impacted our transportation and storage segments during the year ended December 31, 2007. Operating income for the storage segment also improved due to the leasing of additional storage capacity to customers from completed tank expansion projects.

However, our earnings were negatively impacted by a hedging loss of approximately $61.0 million in the second quarter of 2008. Concurrent with the acquisition of the East Coast Asphalt Operations, we entered into certain derivative contracts intended to hedge our exposure to price fluctuations for approximately 30% of the inventory acquired. We entered into these contracts to protect the value of our acquired inventories in the case crude oil prices declined. However, the price of crude oil increased dramatically from the date we entered into the hedges until May 2008, at which time we terminated the contracts prior to their expiration. For the remainder of 2008, we did not have any derivative contracts related to inventories of the East Coast Asphalt Operations, and we managed our commodity risk by managing those physical inventory volumes. We monitor our exposure to commodity prices related to the inventories of our asphalt operations.

Segment Operating Highlights

(Thousands of Dollars, Except Barrel/Day Information)

  

Year Ended December 31,

    
  

2008

  

2007

  

Change

 

Storage:

      

Throughput (barrels/day)(a)

  742,599    800,332    (57,733

Throughput revenues

 $  90,918   $  96,372   $  (5,454

Storage lease revenues

  363,171    314,255    48,916  
            

Total revenues

  454,089    410,627    43,462  

Operating expenses

  246,304    233,675    12,629  

Depreciation and amortization expense

  66,706    62,317    4,389  
            

Segment operating income

 $  141,079   $  114,635   $  26,444  
            

Transportation:

      

Refined products pipelines throughput (barrels/day)

  673,687    678,573    (4,886

Crude oil pipelines throughput (barrels/day)

  392,110    377,640    14,470  
            

Total throughput (barrels/day)

  1,065,797    1,056,213    9,584  

Throughput revenues

 $  317,778   $  296,796   $  20,982  

Operating expenses

  131,943    120,342    11,601  

Depreciation and amortization expense

  50,749    49,946    803  
            

Segment operating income

 $  135,086   $  126,508   $  8,578  
            

Asphalt and Fuels Marketing:

      

Product sales

 $  4,088,169   $  778,391   $  3,309,778  

Cost of product sales

  3,880,796    750,120    3,130,676  

Operating expenses

  80,133    6,737    73,396  

Depreciation and amortization expense

  14,734    423    14,311  
            

Segment operating income

 $  112,506   $  21,111   $  91,395  
            

Consolidation and Intersegment Eliminations:

      

Revenues

 $  (31,266 $  (10,800 $  (20,466

Cost of product sales

  (16,486  (7,148  (9,338

Operating expenses

  (16,132  (3,519  (12,613
            

Total

 $  1,352   $  (133 $  1,485  
            

Consolidated Information:

      

Revenues

 $  4,828,770   $  1,475,014   $  3,353,756  

Cost of product sales

  3,864,310    742,972    3,121,338  

Operating expenses

  442,248    357,235    85,013  

Depreciation and amortization expense

  132,189    112,686    19,503  
            

Segment operating income

  390,023    262,121    127,902  

General and administrative expenses

  76,430    67,915    8,515  

Other depreciation and amortization expense

  3,520    1,607    1,913  
            

Consolidated operating income

 $  310,073   $  192,599   $  117,474  
            

(a)Excludes throughputs related to storage lease revenues.

Storage

Throughputs decreased 57,733 barrels per day and throughput revenues decreased $5.5 million for the year ended December 31, 2008, compared to the year ended December 31, 2007, primarily due to a change in our Corpus Christi (North Beach) crude oil storage tank agreement from a throughput fee agreement to a storage lease agreement effective January 1, 2008. Partially offsetting these decreases were higher throughputs and revenues at terminals serving the McKee refinery mainly due to lower throughputs and revenues in 2007 resulting from the impact of the Valero Energy McKee refinery fire, which shut down the refinery until mid-April 2007.

Storage lease revenues increased by $48.9 million for the year ended December 31, 2008, compared to the year ended December 31, 2007, primarily due to:

an increase of $20.7 million due to completed tank expansion projects at our St. Eustatius, Amsterdam, St. James, Vancouver, Portland and Jacksonville terminals;

an increase of $9.9 million mainly due to increased throughput and new customer contracts at our UK terminal facilities, increased throughputs and product handling revenues at our Amsterdam facility, as well as the effect of foreign exchange rates at our UK and Amsterdam facilities;

an increase of $9.4 million due to a change in our Corpus Christi (North Beach) crude oil storage tank agreement from a throughput fee agreement to a storage lease agreement effective January 1, 2008;

an increase of $2.8 million due to our acquisition of the Wilmington asphalt terminal; and

an increase of $2.7 million at our Point Tupper facility due to increased throughputs, handling charges, reimbursable revenues and dock activity.

Operating expenses increased $12.6 million for the year ended December 31, 2008, compared to the year ended December 31, 2007, primarily due to:

higher salaries and wages of $4.0 million resulting primarily from increased headcount and foreign currency fluctuations;

increased power costs of $3.3 million mainly due to increased fuel consumption at our St. Eustatius and Pt. Tupper facilities, increased costs at our Amsterdam facility and our acquisition of the Wilmington asphalt terminal;

increased costs of $2.9 million primarily at our Texas City terminal related to Hurricane Ike, which made landfall in September 2008; and

an increase of $2.5 million in environmental expense related to an ongoing investigation at one of our refined product terminals.

Depreciation and amortization expense relatesincreased $4.4 million for the year ended December 31, 2008, compared to corporate assets.the year ended December 31, 2007, primarily due to the completion of various terminal expansion projects.

Transportation

Throughputs increased 9,584 barrels per day and revenues increased $21.0 million for the year ended December 31, 2008, compared to the year ended December 31, 2007, primarily due to increased throughputs and revenues of $21.5 million at pipelines serving the McKee refinery. 2007 revenues were adversely affected by the impact of the Valero Energy McKee refinery fire. 2008 revenues also increased due to higher tariffs on all of the refined product and crude oil pipelines as the annual index adjustment was effective July 1, 2008.

These increases were partially offset by decreased revenues and throughputs on our Houston pipeline in 2008 as one of our customers began to export more product rather than shipping inland through our pipeline. In addition, the Wynnewood pipeline experienced lower revenues due to decreased long-haul deliveries in 2008. Also, throughputs decreased mainly due to a turnaround, crude supply interruptions and other operational issues at a refinery served by the Wynnewood pipeline. Reduced demand in 2008 resulting from a prolonged winter and flooding in the Midwest and higher commodity prices, along with record throughputs in 2007, contributed to lower throughputs on our East Pipeline.

Operating expenses for this segment increased $11.6 million for the year ended December 31, 2008, compared to the year ended December 31, 2007, primarily due to increased power costs as a result of the increase in throughputs on pipelines serving the McKee refinery, higher natural gas prices and the impact of significantly lower product prices on product imbalances on the East Pipeline. Also, salaries and wages and internal overhead expense increased, both due primarily to increased headcount. These increases were partially offset by decreased maintenance and environmental expenses.

Asphalt and Fuels Marketing

Sales and cost of product sales increased $3,309.8 million and $3,130.7 million, respectively, during the year ended December 31, 2008, compared to the year ended December 31, 2007, mainly due to:

an increase of $2,496.3 million and $2,347.5 million in sales and cost of product sales, respectively, from our acquisition of the East Coast Asphalt Operations in March 2008. Cost of product sales for the year ended December 31, 2008 includes the $61.0 million hedging loss discussed in the Annual Highlights above;

an increase of $585.7 million and $576.0 million in sales and cost of product sales, respectively, associated with our fuels marketing operations that began in the second quarter of 2007; and

an increase of $233.0 million and $210.8 million for sales and cost of product sales, respectively, associated with our bunker fuel operations due to an increase in the market price per metric ton at our St. Eustatius facility and increased sales at our Point Tupper facility, which resumed the sale of bunker fuel in the second quarter of 2008. Cost of sales includes a hedge gain of $28.1 million primarily associated with bunker fuel sales at our Point Tupper facility.

Operating expenses increased by $73.4 million for the year ended December 31, 2008, compared to the year ended December 31, 2007, primarily due to:

an increase of $58.3 million from our acquisition of the East Coast Asphalt Operations in March 2008; and

an increase of $13.9 million related to marine expenses mainly due to increased tug and barge rental costs as agreements for new tugs and barges at St. Eustatius were effective January 1, 2008.

Depreciation and amortization expense increased $14.3 million for the year ended December 31, 2008, compared to the year ended December 31, 2007, due to our acquisition of the East Coast Asphalt Operations in March 2008.

General

General and administrative expenses increased by $8.5 million for the year ended December 31, 2008, compared to the year ended December 31, 2007, primarily due to increased salary and wages resulting from higher headcount and additional costs required for the Partnership’s growth and separation from Valero Energy. In addition, compensation expense associated with unit options and restricted units increased as a result of the increase in the number of awards outstanding, partially offset by a decrease in our unit price.

Other depreciation and amortization expense relates to corporate assets.

Interest expense, net increased by $14.3 million for the year ended December 31, 2008, compared to the year ended December 31, 2007, primarily due to an increase in our outstanding debt balance resulting from our issuance of $350.0 million of 7.65% senior notes in April 2008 to finance the acquisition of the East Coast Asphalt Operations and increased borrowings under our revolving credit agreement to fund a portion of our capital expenditures and working capital requirements. This was partially offset by a decrease in interest rates, including a decrease in the variable interest rate paid on our interest rate swaps, which hedge a portion of our fixed-rate senior notes, and our revolving credit facility.

Other income, net consisted of the following:

 

   

Year Ended December 31,

   
   

2008

  

2007

  
   (Thousands of Dollars)  

Sale of interest in Skelly-Belvieu

  $   18,867  $   -   

Sale or disposal of fixed assets

    7,589    7,869   

Business interruption insurance

    3,504    12,492   

2007 Services Agreement termination fee

    -    13,000   

Legal settlements

    -    5,758   

Foreign exchange gains (losses)

    5,888    (6,261 

Other

    1,891    5,972   
            

Other income, net

  $   37,739  $   38,830   
            

See Note 2018 of Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplemental Data” for further information regarding the components of other income.

Year Ended December 31, 2007 Compared to Year Ended December 31, 2006

Financial Highlights

(Thousands of Dollars, Except Unit and Per Unit Data)

   

Year Ended December 31,

  

Change

 
   

2007

  

2006

  

Statement of Income Data:

   

Revenues:

    

Service revenue

  $    696,623  $    636,154  $    60,469 

Product sales

   778,391   501,107   277,284 
             

Total revenues

   1,475,014   1,137,261   337,753 
             

Costs and expenses:

    

Cost of product sales

   742,972   466,276   276,696 

Operating expenses

   357,235   312,604   44,631 

General and administrative expenses

   67,915   45,216   22,699 

Depreciation and amortization expense

   114,293   100,266   14,027 
             

Total costs and expenses

   1,282,415   924,362   358,053 
             

Operating income

   192,599   212,899   (20,300)

Equity earnings from joint ventures

   6,833   5,882   951 

Interest expense, net

   (76,516)  (66,266)  (10,250)

Other income (expense), net

   38,830   3,252   35,578 
             

Income from continuing operations before income tax expense

   161,746   155,767   5,979 

Income tax expense

   11,448   5,861   5,587 
             

Income from continuing operations

   150,298   149,906   392 

Income (loss) from discontinued operations, net of income tax

   -   (376)  376 
             

Net income

   150,298   149,530   768 

Less net income applicable to the general partner

   (21,063)  (16,910)  (4,153)
             

Net income applicable to limited partners

  $129,235  $132,620  $(3,385)
             

Net income (loss) per unit applicable to limited partners:

    

Continuing operations

  $2.74  $2.84  $(0.10)

Discontinued operations

   -   (0.01)  0.01 
             

Net income

  $2.74  $2.83  $(0.09)
             

Weighted average number of basic and diluted units outstanding

   47,158,790   46,809,749   349,041 

Annual Highlights

Net income increased $0.8 million for the year ended December 31, 2007, compared to the year ended December 31, 2006, primarily due to a significant increase in other income and slightly higher segment operating income, partially offset by increased general and administrative expense, interest expense and income tax expense.

Total segment operating income increased $2.4 million for the year ended December 31, 2007, compared to the year ended December 31, 2006, primarily due to a $6.1 million increase in operating income for the storage segment and a $3.8 million increase in operating income for the transportation segment, partially offset by a $5.8 million decrease in operating income for the asphalt and fuels marketing segment.

The throughputs on the storage and transportation segments were affected by a fire at the McKee refinery in February 2007, which shut down the refinery through mid-April 2007. After the refinery restarted in mid-April 2007, its throughputs increased throughout the second quarter, and it was near capacity by July 2007.

Segment Operating Highlights

(Thousands of Dollars, Except Barrel/Day Information)

   

Year Ended December 31,

  

Change

 
   

2007

  

2006

  

Storage:

    

Throughput (barrels/day)(a)

   800,332   774,743   25,589 

Throughput revenues

  $    96,372  $    97,179  $(807)

Storage lease revenues

   314,255   266,234   48,021 
             

Total revenues

   410,627   363,413   47,214 

Operating expenses

   233,675   201,806   31,869 

Depreciation and amortization expense

   62,317   53,121   9,196 
             

Segment operating income

  $114,635  $108,486  $        6,149 
             

Transportation:

    

Refined products pipelines throughput (barrels/day)

   678,573   711,476   (32,903)

Crude oil pipelines throughput (barrels/day)

   377,640   421,666   (44,026)
             

Total throughput (barrels/day)

   1,056,213   1,133,142   (76,929)

Throughput revenues

  $296,796  $281,010  $15,786 

Operating expenses

   120,342   111,151   9,191 

Depreciation and amortization expense

   49,946   47,145   2,801 
             

Segment operating income

  $126,508  $122,714  $3,794 
             

Asphalt and Fuels Marketing:

    

Product sales

  $778,391  $501,107  $  277,284 

Cost of product sales

   750,120   471,576   278,544 

Operating expenses

   6,737   2,616   4,121 

Depreciation and amortization expense

   423   -   423 
             

Segment operating income

  $21,111  $26,915  $(5,804)
             

Consolidation and Intersegment Eliminations:

    

Revenues

  $(10,800) $(8,269) $(2,531)

Cost of product sales

   (7,148)  (5,300)  (1,848)

Operating expenses

   (3,519)  (2,969)  (550)

Depreciation and amortization expense

   1,607   -   1,607 
             

Total

  $(1,740) $-  $(1,740)
             

Consolidated Information:

    

Revenues

  $1,475,014  $1,137,261  $337,753 

Cost of product sales

   742,972   466,276   276,696 

Operating expenses

   357,235   312,604   44,631 

Depreciation and amortization expense

   114,293   100,266   14,027 
             

Segment operating income

   260,514   258,115   2,399 

General and administrative expenses

   67,915   45,216   22,699 
             

Consolidated operating income

  $192,599  $212,899  $(20,300)
             

(a)

Excludes throughputs related to storage lease revenues.

Storage

Throughputs increased 25,589 barrels per day for the year ended December 31, 2007, compared to the year ended December 31, 2006, primarily due to a change in the Corpus Christi (North Beach) crude oil storage tank agreement from a storage lease to a throughput fee agreement effective January 1, 2007. Throughputs for the Corpus Christi (North Beach) crude oil storage tanks were not reported prior to January 1, 2007. This increase was partially offset by decreased throughputs related to terminals serving the McKee refinery. In spite of the increased throughputs, throughput revenues decreased by $0.8 million for the year ended December 31, 2007, compared to the year ended December 31, 2006, primarily due to lower revenues at our terminals serving the McKee refinery and turnarounds and operating issues at the refineries served by our crude oil storage tanks.

Storage lease revenues increased by $48.0 million for the year ended December 31, 2007, compared to the year ended December 31, 2006, primarily due to:

an increase of $19.2 million resulting from the St. James terminal acquisition in December 2006;

an increase in storage lease terminal revenues of $24.7 million mainly due to additional customers, increased storage utilization and contract extensions by current customers, higher reimbursable project revenue and the effect of foreign exchange rates; and

an increase in revenues of $4.1 million at our St. Eustatius facility due to leasing additional storage capacity that resulted from completed tank expansion projects.

Operating expenses increased $31.9 million for the year ended December 31, 2007, compared to the year ended December 31, 2006, primarily due to higher reimbursable project expenses. Reimbursable project expenses are charged back to our customers, and its increase is consistent with the increase in reimbursable project revenues.Operating expenses also increased due to higher maintenance and regulatory expenses, higher salaries and wages, the acquisition of the St. James terminal in December 2006, and higher marine expenses due to increased vessel calls at St. Eustatius and Point Tupper.

Depreciation and amortization expense increased $9.2 million for the year ended December 31, 2007, compared to the year ended December 31, 2006, due to the acquisition of the St. James terminal in December 2006 and the completion of various capital projects, including two phases of the St. Eustatius tank expansion.

Transportation

Throughputs decreased 76,929 barrels per day for the year ended December 31, 2007, compared to the year ended December 31, 2006, primarily due to the impact of the McKee refinery fire, offset by increased throughputs on the East Pipeline, Ammonia Pipeline and Burgos Pipeline. Despite lower overall throughputs, revenues increased by $15.8 million for the year ended December 31, 2007, compared to the year ended December 31, 2006, primarily due to:

higher tariff rates on virtually all of the refined product pipelines as the annual index adjustment was effective July 1, 2007;

increased revenues and throughputs on the East Pipeline due to the closing of one of our competitor’s terminals in the second quarter of 2007 and increased throughputs to supply the Colorado market. The East Pipeline also experienced increased revenues due to a turnaround at the Ponca City refinery in prior year and increased long haul deliveries in 2007;

increased revenues on the Ammonia Pipeline due to a record corn crop; and

increased revenues on the Burgos pipeline due to our receipt of throughput deficiency payments in 2007. In addition, revenues increased due to a full year of operations of the Burgos pipeline, which commenced operations in the middle of the third quarter of 2006.

Operating expenses increased $9.2 million for the year ended December 31, 2007, compared to the year ended December 31, 2006, primarily due to higher maintenance and environmental costs and higher internal overhead costs mainly due to increased headcount. These increases were partially offset by decreased power costs due to downtime from the McKee refinery fire.

Depreciation and amortization expense increased $2.8 million for the year ended December 31, 2007, compared to the year ended December 31, 2006, mainly due to increased amortization of deferred costs in connection with the throughput deficiency payments discussed above. In addition, depreciation and amortization expense increased due to the completion of various capital projects.

Asphalt and Fuels Marketing

Sales and cost of product sales increased $277.3 million and $278.5 million, respectively, during the year ended December 31, 2007, compared to the year ended December 31, 2006, mainly due to:

an increase of $115.4 million and $121.3 million in sales and cost of product sales, respectively, associated with certain marketing operations that began in the second quarter of 2007. For the year ended December 31, 2007, cost of product sales includes $7.5 million related to the change in fair value of certain derivative instruments; and

an increase of $171.5 million and $159.8 million for sales and cost of sales, respectively, associated with our bunker fuel operations primarily due to increased vessel calls at our St. Eustatius facility, partially offset by a decrease in bunker fuel sales of $10.9 million at our Point Tupper facility due to decreased vessel calls.

Operating expenses increased by $4.1 million for the year ended December 31, 2007, compared to the year ended December 31, 2006, primarily due to salaries and wages and terminal storage fees relating to the marketing operations that began in 2007.

General

General and administrative expenses increased by $22.7 million for the year ended December 31, 2007, compared to the year ended December 31, 2006, primarily due to the following:

increased expenses associated with unit option and restricted unit compensation expense as a result of the increase in the number of awards outstanding, partially offset by a decrease in our unit price;

increased headcount primarily resulting from a reduction in administrative services received from Valero Energy and increased information systems costs as a result of the separation from Valero Energy;

increased professional fees primarily related to external legal costs; and

increased rent expense related to our new headquarters.

Interest expense increased by $10.3 million for the year ended December 31, 2007, compared to the year ended December 31, 2006, primarily due to higher average debt balances arising from borrowings used to fund the acquisition of the St. James crude oil storage facility in December 2006 and various terminal expansion projects combined with higher interest rates, partially offset by capitalized interest.

Other income increased by $35.6 million for the year ended December 31, 2007, compared to the year ended December 31, 2006, primarily due to a $13.0 million payment from Valero Energy for exercising its option to terminate the 2007 Services Agreement, business interruption insurance income of $12.5 million associated with the McKee refinery fire, the sale of a net profit interest in Wyoming coal properties for $7.3 million and a gain of $5.2 million related to a settlement for damages at our Westwego terminal. Partially offsetting these increases are foreign exchange losses totaling approximately $6.3 million primarily relating to our Canadian subsidiary.

Income tax expense increased $5.6 million for the year ended December 31, 2007, compared to the year ended December 31, 2006. Income tax expense was higher in 2007 primarily due to the impact of the Texas margin tax effective January 1, 2007, recording a valuation allowance related to a capital loss carryforward in Canada and other adjustments. These increases were partially offset by reductions in the United Kingdom and Canadian income tax rates in 2007.

OUTLOOK

Overall, we expect our results for 2010 to improve compared to 2009. However, the outlook on our operations could change depending on the pace of the economic recovery and other economic conditions.

Transportation Segment

ForWe expect the first quarter oftransportation segment results for 2010 to be comparable to slightly lower than 2009. Throughputs for 2010 are forecasted to increase slightly compared to 2009, we expect a heavy planned refinery maintenance schedule, primarily at the Valero Energy refineries we serve, to negatively affect our pipeline throughputs. Revenues generated from our pipelines depend upon the amount of throughputs. When refineries undergo maintenance, generally they also curtail production, which lowers throughputs for crude oil and refined products causing our throughputs and revenues to decline. For the full year of 2009, we expect a lighter refinery maintenance schedule, additional shippers and the completion of a pipeline expansion project will offset the effects of the recession and the weak first quarter described above. Thus, barring any major unplanned turnaround activity and excluding the impact from the sale of pipelines in 2009. However, we expect overall pipeline throughputs in 2009 to be comparable to 2008. Additionally, we expect to increase the tariffs on our pipelines effectiveregulated by the FERC, which adjust annually based upon changes in the producer price index, to decline slightly in July, 1, 2009, whichwhen the adjustment takes effect. Even with the effect of the tariff rate decline, our overall tariff rate for 2010 should have a positive effect onbe slightly higher than 2009. If throughputs increase or if the cost of natural gas increases, we would expect our revenuespower expenses to increase in 2010 compared to 2009. The pace of the economic recovery, changes to refinery maintenance schedules, or other factors that impact overall demand for products we transport could affect our throughputs and results of operations.revenues.

Storage Segment

For the first quarter of 2009,2010, we expect our terminal throughputs to decline due to heavy planned refinery maintenance primarily at the Valero Energy refineries we serve. Several of the assets included inearnings for the storage segment store crude oil and refined products for refineries owned by Valero Energy. Revenues for these assets depend upon throughputs rather than fixed rental fees, so when the refineries undergo maintenance our throughputs and related revenues decline. However, we do notto increase compared to 2009. We expect these lower throughputs to significantly impact our revenues or results of operations for the full year of 2009 because most of our revenues result from long-term storage lease contracts, which are not throughput dependent. Of our storage lease contracts, approximately 70% have remaining terms between one and ten years. For the 30% of our storage contracts expiring within the next year, we believe we can renew these contracts at similar or better terms provided the present contango markets continue to drive demand for storage. Additionally, we expect our revenues and results of operations for 2009 to benefit from annual index increases to storage fee rates on most of our multi-year contracts and a full year’s contribution of key terminal expansion projects completed in 20082009 and from new internal growth projects, a portion of which should be completed in 2010. In addition, we expect to benefit from renewal rates that increased significantly in 2009.

Asphalt and Fuels Marketing Segment

The earnings of the asphalt and fuels marketing segment largely depend upon the margin earned by the East Coast Asphalt Operations.our asphalt operations. Our margin results from the difference between the sales prices of our products and the purchase prices of our raw materials, principally crude oil. The prices of crude oil and the products produced by the East Coast Asphalt Operationsour asphalt operations fluctuate in response to many factors, such as changes in supply, demand, seasonality, market uncertainties and other factors.

In the first quarter of 2009, we expect our asphalt sales and margins to remain low due to typical seasonal factors including decreased road construction during colder months. For the full year of 2009, we expect our results to be higher than 2008. Last year asphalt demand remained below 2007 levels; however, lower supply resulting from fewer imports and reduced domestic production more than offset the effects of lower demand and resulted in higher prices and higher margins. We expect many of the same factors present in 2008 that contributed positively to our results of operations to continue in 2009. Additionally, on February 17, 2009, The American Recovery and Reinvestment Act of 2009 was signed into law, which includes funding for transportation infrastructure that could increase asphalt demand in 2009 and beyond. Longer term, we believe additional refinery coker expansions will continue to tighten asphalt markets resulting in better-than-historic margins.

In recent months, the Organization of the Petroleum Exporting Countries announced its intention to reduce crude oil production in response to dramatically lower demand for refined products. As a result, we received notice in January 2009 that our scheduled deliveries of Boscan crude oil would be reduced by 600,000 barrels in February and March from the amounts specified in our crude supply agreement with an affiliate of Petroleos de Venezuela S.A (PDVSA). To date, we have replaced the volumes lost from PDVSA with alternative grades of crude oil purchased on the spot market. We have not received notification of any further supply reductions from PDVSA. If the supply reductions extend beyond March at their current levels, we believe we can continue to replace that supply with other asphaltic crudes without a material impact to our results of operations. However, in the event PDVSA further reduces the deliveries of Boscan crude oil, we may experience reduced refinery run rates and reduced production that could negatively impact our results of operations and our cash flows.

Overall, we expect our results for the full year of 20092010 to improve compared to 2008. However, depending on2009. Specifically, we expect asphalt supply levels to remain below recent averages due to lower U.S. refinery utilization rates, resulting in lower refinery production, including asphalt, and the severitycontinued lack of asphalt imports. Assuming the spending associated with the American Recovery and duration of this recession, orRevitalization Act and other adverse economic conditions,federal highway and public transportation programs increases in 2010 over 2009 levels, we would expect an increase in demand for asphalt. If supply levels remain lower than historical averages and demand increases, it should result in a higher margin per barrel and increased sales volumes in our operations could be negatively impacted.asphalt operations.

LIQUIDITY AND CAPITAL RESOURCES

General

Our primary cash requirements are for distributions to partners, working capital requirements, including inventory purchases, debt service, reliability and strategic and other capital expenditures, acquisitions and normal operating expenses. On an annual basis, we typicallyattempt to fund our operating expenses, interest expense, reliability capital expenditures and distribution requirements with cash generated from our operations. If we do not generate sufficient cash from our operations to fund day-to-day operating and general and administrative expenses, reliability capital expenditures, interest expense and distribution requirements. We also havemeet those requirements, we utilize available borrowing capacity under our existing revolving credit facility and, to the extent necessary, we may raise additional funds raised through equity or debt offerings under our $3.0 billion shelf registration statement tostatement. Additionally, we typically fund our strategic capital expenditures from external sources, primarily borrowings under our revolving credit agreement or other cash requirements not funded from operations.funds available under our $3.0 billion shelf registration statement. However, there can be no assurance regarding the availability of any additionalour ability to raise funds by issuing debt or whether such additional funds will be availableequity depends on terms acceptable to us.many factors beyond our control. The

volatility of the capital and credit markets could affectrestrict our ability to issue debt or equity or may increase our cost of capital and abilitybeyond rates acceptable to access the capital and credit markets.us.

Cash Flows for the Years Ended December 31, 2009, 2008 2007 and 20062007

The following table summarizes our cash flows from operating, investing and financing activities:

 

  

Year Ended December 31,

   

Year Ended December 31,

 
  

2008

 

2007

 

2006

   

2009

 

2008

 

2007

 
  (Thousands of Dollars)   (Thousands of Dollars) 

Net cash provided by (used in):

              

Operating activities

  $485,181  $222,672  $250,811   $   180,582   $   485,181   $   222,672  

Investing activities

   (956,517)  (238,396)  (213,234)    (167,705   (956,517   (238,396

Financing activities

   440,063   37,060   (3,899)    (2,672   440,063     37,060  

Effect of foreign exchange rate changes on cash

   (13,190)  (336)  (894)    6,426     (13,190   (336
                          

Net increase in cash and cash equivalents

  $(44,463) $21,000  $32,784 

Net increase (decrease) in cash and cash equivalents

  $   16,631   $   (44,463 $   21,000  
                          

For the year ended December 31, 2009 we generated cash from operations of $180.6 million compared to $485.2 million in the prior year. The decline resulted primarily from lower net income of $224.9 million in 2009 compared to $254.0 million in 2008 and higher investments in working capital in 2009 compared to 2008. In 2009, we increased our working capital by $152.3 million compared to a decrease of $133.0 million in 2008. Within working capital, our inventory balances increased by $156.2 million in 2009 compared to a decrease of $194.0 million in 2008. Because of our significant investment in working capital and lower earnings in 2009, our cash generated from operations did not exceed our cash requirements for reliability capital expenditures and distributions. As a result, we utilized borrowings under our revolving credit agreement as well as the proceeds from our equity offering to fund that shortfall and our strategic capital expenditures. Additionally, we received $41.1 million from the sale of assets and insurance proceeds, which is included in cash flows from investing activities.

Net cash provided by operating activities for the year ended December 31, 2008 was $485.2 million compared to $222.7 million for the year ended December 31, 2007. The increase in cash generated from operating activities is primarily due to higher net income of $254.0 million for the year ended December 31, 2008 compared to net income of $150.3 million for the year ended December 31, 2007. Also, working capital decreased $133.0 million in 2008 providing an increase in cash, whereas working capital increased $21.3 million in 2007. Within working capital, inventory decreased $194.0 million for the year ended December 31, 2008, primarily duecompared to the operations of the asphalt and fuels marketing segment. We obtained inventory with our acquisition of the East Coast Asphalt Operations, and the inventory balance declined with the seasonality of the asphalt operations. However, an increase of $71.5 million in accounts receivable of $52.4 million, also primarily related to the asphalt and fuels marketing segment, partially offset the inventory decrease.2007. Cash flows from operations for the year ended December 31, 2008 also include proceeds from business interruption insurance of $3.5 million compared to $12.5 million for the year ended December 31, 2007.

Net cash provided by operating activities for the year ended December 31, 2008 was used to fund distributions to unitholders and the general partner in the aggregate amount of $241.9 million. The proceeds from long-term and short-term debt borrowings, net of repayments, our issuance of common units and senior notes, combined with cash on hand, were used to fund the acquisition of the East Coast Asphalt Operations and our strategic capital expenditures primarily related to various terminal expansion projects.

Net cash provided by operating activities for the year ended December 31, 2007 was $222.7 million compared to $250.8 million for the year ended December 31, 2006 primarily due changes in working capital accounts. Working capital increased $21.3 million in 2007 providing a decrease in cash, whereas working capital decreased $10.7 million in 2006. Within working capital, accounts receivable and inventory increased by $22.1 million and $71.5 million, respectively, compared to 2006 primarily due to the operations of the asphalt and fuels marketing segment, particularly an increase in inventory associated with marketing of asphalt, gasoline and distillates which began in 2007. Offsetting the increases in inventory and accounts receivable was an increase in accounts payable of $72.9 million, also primarily related to the marketing of asphalt, gasoline and distillates. Cash flows from operations for the year ended December 31, 2007 also includes proceeds from business interruption insurance of $12.5 million.

Net cash provided by operating activities for the year ended December 31, 2007 was used to fund distributions to unitholders and the general partner in the aggregate amount of $197.3 million. The proceeds from long-term debt borrowings, net of repayments, were used to fund a portion of our capital expenditures, primarily related to various terminal expansion projects. Additionally, we issued 2,600,000 common units for proceeds of $146.1 million, including a contribution from our general partner, which were used to repay borrowing on our long-term debt.

2007 Revolving Credit Agreement

Our five-year revolving credit agreement (theThe lenders under the 2007 Revolving Credit Agreement) is diversified with 24 participating banks. However, the participating banksAgreement include Lehman Brothers Bank, FSB (LB Bank), a subsidiary of Lehman Brothers Holdings Inc. (Lehman), which filed for bankruptcy protection in October 2008. LB Bank’s participation in the 2007 Revolving Credit Agreement totaled $42.5 million, of which we had $17.0$5.0 million remained outstanding as of December 31, 2008.2009. As a result of Lehman’s bankruptcy filing in October 2008, LB Bank has elected not to fund its pro rata share of any future borrowings we request, which reducesreduced the total commitment under the 2007 Revolving Credit Agreement to

approximately $1.2 billion. Excluding LB Bank’s participation, we had $610.7$624.6 million available for borrowing under the 2007 Revolving Credit Agreement as of December 31, 2008.2009. If other lenders under the 2007 Revolving Credit Agreement file for bankruptcy or experience severe financial hardship due to recent disruptions and steep declines in the global financial markets and generally severely tightening credit supply, they may not honor their pro rata share of our borrowing requests.

The 2007 Revolving Credit Agreement requires that we maintain certain financial ratios and includes other restrictive covenants, including a prohibition on distributions if any defaults, as defined in the agreements, exist or would result from the distribution. The 2007 Revolving Credit Agreement requires us to maintain, as of the end of each four consecutive fiscal quarters, a consolidated debt coverage ratio (consolidated indebtedness to consolidated EBITDA, as defined in the 2007 Revolving Credit Agreement) not to exceed 5.00-to-1.00, which may restrict the amount we can borrow without exceeding the maximum allowed limit to an amount less than the total amount available for borrowing. As of December 31, 2009, the consolidated debt coverage ratio was 4.1x.

The 2007 Revolving Credit Agreement matures in December 2012, and we do not have any other significant debt maturing until 2012 and 2013, when four of our five senior notes become due.

Shelf Registration Statement

Our shelf registration statement on Form S-3 permits us to offer and sell various types of securities, including NuStar Energy L.P. common units and debt securities of NuStar Logistics and NuPOP, having an aggregate value of up to $3.0 billion (the 2007 Shelf Registration Statement). We filed the 2007 Shelf Registration Statement to gain additional flexibility in accessing capital markets for, among other things, the repayment of outstanding indebtedness, working capital, capital expenditures and acquisitions. As of December 31, 2008,2009, we had $2.3have issued approximately $1.0 billion available under our $3.0 billion shelf registration statement.

If the volatility of the capital markets continues,become more volatile, as was seen in recent years, our access to the capital markets may be limited, or we could face increased costs when accessing the capital markets. In addition, it is possible that our ability to access the capital and credit markets may be limited by these or other factors at a time when we would like or need to do so, which could have an impact on our ability to refinance maturing debt and/or react to changing economic and business conditions.

NuStar Logistics’ 7.65% Senior Notes.    On April 4, 2008, NuStar Logistics issued $350.0 million of 7.65% senior notes under our $3.0 billion shelf registration statement for net proceeds of $346.2 million. The net proceeds were used to repay a portion of the outstanding principal balance under our 2007 Revolving Credit Agreement, which was used to fund our acquisition of the East Coast Asphalt Operations. Please refer to Note 13 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for a more detailed discussion of 7.65% senior note offering.

Equity Offerings.    Offering.In April 2008,November 2009, we issued 5,050,8005,750,000 common units representing limited partner interests at a price of $48.75$52.45 per unit. We received net proceeds of $236.2$288.8 million and a contribution of $5.0$6.2 million from our general partner to maintain its 2% general partner interest. The net proceeds were used mainly to repay the $124.0 million balance under our then-active term loan agreement and a portion ofreduce the outstanding principal balance under our 2007 Revolving Credit Agreement. See Notes Payable below for discussion on our term loan agreement.

On November 19, 2007, we issued 2,600,000 common units representing limited partner interests at a price of $57.20 per unit. We received net proceeds of $143.1 million and a contribution of $3.0 million from our general partner to maintain its 2% general partner interest. The proceeds were used to repay a portion of the outstanding principal balance under our then-active $600 million revolving credit agreement.

Capital Requirements

Our operations are capital intensive, requiring significant investments to maintain, upgrade or enhance existing operations and to comply with environmental and safety laws and regulations. Our capital expenditures consist of:

reliability capital expenditures, such as those required to maintain equipment reliability and safety and to address environmental and safety regulations; and

strategic and other capital expenditures, such as those to expand and upgrade pipeline capacity or asphalt refinery operations and to construct new pipelines, terminals and storage tanks. In addition, strategic capital expenditures may include acquisitions of pipelines, terminals or storage tank assets.assets, as well as certain capital expenditures related to support functions.

During the year ended December 31, 2008,2009, we incurred reliability capital expenditures of $55.7$45.0 million, primarily related to maintenance upgrade projects at our terminals and pipelines. Strategic and other capital expenditures for the year ended December 31, 20082009 of $146.5$163.6 million primarily related to a pipeline expansion on the Amsterdam, St. James,southern end of the East Pipeline and projects at our Texas City and Jacksonville tank expansions and other terminal expansion projects.terminal.

For 2009,2010, we budgetedexpect to incur approximately $147.0$375.0 to $400.0 million of capital expenditures, including approximately $67.0$55.0 to $60.0 million for reliability capital projects and $80.0$320.0 to $340.0 million for strategic projects, which is lower than 2008 in light of the current economic environment and capital market conditions.expenditures. We continue to evaluate our capital budget and make changes as

economic conditions warrant. IfDepending upon current economic conditions, warrant, our actual capital expenditures for 20092010 may exceed or be lower than the budgeted amounts. We believe cash generated from operations, combined with other sources of liquidity previously described, will be sufficient to fund our capital expenditures in 2009,2010, and our internal growth projects can be accelerated or scaled back depending on the capital markets.

Working Capital Requirements

The operations of the asphalt and fuels marketing segment requiresrequire us to makeinvest substantial investmentsamounts in working capital. For example, in 2009 our inventory balances increased by $156.2 million due to higher volumes and higher average prices. Crude oil volumes increased substantially at December 31, 2009 over December 31, 2008 due to lower production in 2009. Additionally, the average cost of our crude oil inventory was significantly higher at December 31, 2009 compared to December 31, 2008 due to the collapse in crude oil prices in the fourth quarter of 2008. Our refined product inventory volumes at December 31, 2009 also increased over the prior year as a result of our strategy to take advantage of contango markets, whereby we purchase inventory at seasonally low prices and store it until we can sell it at seasonally higher prices. To take advantage of contango markets, we may store inventory over an extended period of time, as occurred in 2009. Additionally, the average cost of our refined product inventories at December 31, 2009 increased compared to the prior year due to the significant decline in refined product prices in the fourth quarter of 2008 associated with the decline in crude oil prices.

Higher inventory balances would typically also result in higher amount of accounts payable, which would reduce working capital. However, with respect to our contango and asphalt winterfill strategies, which involve storing inventory for an extended period, we typically pay the associated accounts payable prior to selling the inventory. IncreasesDue to the potential for this discrepancy in commodity prices could causetiming between paying our invoice and selling our inventory, increases in our accounts payable will not always offset increases in our inventory balances within our working capital. As a result, the volume of inventory we maintain and the average cost of those inventories associated with our contango and asphalt winterfill strategies can significantly affect our working capital requirementsbalance.

In 2008 we acquired the East Coast Asphalt Operations, which included approximately $327.3 million allocated to increase, which could affect our liquidity. Our working capital requirements will varyinventories included in the purchase. The purchase of the inventories included with the seasonal natureEast Coast Asphalt Operations was considered part of asphalt demandthe acquisition price and recorded in the Statement of Cash Flows as we build and storean investing activity. Therefore, our cash flows from operations in 2008 reflect a reduction in inventories during periods of lower demand in orderdespite the fact that our inventory balance at December 31, 2008 increased compared to sell it during periods of higher demand. This seasonal nature of demand will also affect the accounts receivable and accounts payable balances, which will vary depending on timing of payments.December 31, 2007.

Distributions

NuStar Energy’s partnership agreement, as amended, determines the amount and priority of cash distributions that our common unitholders and general partner may receive. The general partner receives a 2% distribution with respect to its general partner interest. The general partner is also entitled to incentive distributions if the amount we distribute with respect to any quarter exceeds $0.60 per unit. For a detailed discussion of the incentive distribution targets, please read Item 5. “Market for Registrant’s Common Units, Related Unitholder Matters and Issuer Purchases of Common Units.”

The following table reflects the allocation of total cash distributions to the general and limited partners applicable to the period in which the distributions are earned:

 

 

Year Ended December 31,

  

Year Ended December 31,

 

2009

 

2008

 

2007

  

2008

  

2007

  

2006

 (Thousands of Dollars, Except Per Unit Data)
  (Thousands of Dollars, Except Per Unit Data)

General partner interest

  $5,058  $4,092  $3,742 $  5,430 $  5,058 $  4,092

General partner incentive distribution

   25,294   18,426   14,778  28,712  25,294  18,426
                  

Total general partner distribution

   30,352   22,518   18,520  34,142  30,352  22,518

Limited partners’ distribution

   222,470   182,076   168,515  237,308  222,470  182,076
                  

Total cash distributions

  $252,822  $204,594  $187,035 $  271,450 $  252,822 $  204,594
                  

Cash distributions per unit applicable to limited partners

  $4.085  $3.835  $3.600 $  4.245 $  4.085 $  3.835
                  

Actual distribution payments are made within 45 days after the end of each quarter as of a record date that is set after the end of each quarter.

In January 2009,2010, we declared a quarterly cash distribution of $1.0575$1.065 that was paid on February 12, 20092010 to unitholders of record on February 5, 2009.2010. This distribution related to the fourth quarter of 20082009 and totaled $65.8$73.4 million, of which $8.2$9.3 million represented the general partner’s share of such distribution. The general partner’s distribution included a $6.9$7.8 million incentive distribution.

Long-Term Debt Obligations

We are a party to the following long-term debt agreements:

the 2007 Revolving Credit Agreement due December 10, 2012, with a balance of $525.1 million as of December 31, 2009;

NuStar Logistics’ 7.65%6.875% senior notes due AprilJuly 15, 20182012 with a face value of $350.0$100.0 million, 6.05% senior notes due March 15, 2013 with a face value of $229.9 million and 6.875%7.65% senior notes due JulyApril 15, 20122018 with a face value of $100.0$350.0 million;

NuPOP’s 7.75% senior notes due February 15, 2012 and 5.875% senior notes due June 1, 2013 with an aggregate face value of $500.0 million;

the 2007 Revolving Credit Agreement due December 10, 2012;

the £21 million term loan due December 11, 2012 (UK Term Loan);

the $56.2 million revenue bonds due June 1, 2038 associated with the St. James terminal expansion (Gulf Opportunity Zone Revenue Bonds);

the £21 million term loan due December 11, 2012 (UK Term Loan); and

the $12.0 million note payable in annual installments through December 31, 2015 to the Port of Corpus Christi Authority of Nueces County, Texas, with a balance of $3.5 million as of December 31, 2009, associated with the construction of a crude oil storage facility in Corpus Christi, Texas (Port Authority of Corpus Christi Note Payable).

Management believes that we are in compliance with all ratios and covenants of the UK Term Loan as of December 31, 2009, which are substantially the same as the 2007 Revolving Credit Agreement. Our other long-term debt obligations do not contain any financial covenants. However, a default under any of our debt instruments would be considered an event of default under all of our debt instruments. Please refer to Note 1311 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for a more detailed discussion of our long-term debt agreements.

Credit Ratings

The following table reflects the outlook and ratings that have been assigned to the debt of our wholly owned subsidiaries as of December 31, 2009:

Standard &
Poor’s
Moody’sFitch

Outlook

StableStableStable

Ratings

BBB-Baa3BBB-

Interest Rate Swaps

We are a party to interest rate swap agreements to manage our exposure to changes in interest rates. The interest rate swap agreements have an aggregate notional amount of $167.5 million, of which $60.0 million is tied to the maturity of the 6.875% senior notes and $107.5 million is tied to the maturity of the 6.05% senior notes. Under the terms of the interest rate swap agreements, we will receive a fixed rate (6.875% and 6.05% for the $60.0 million and $107.5 million of interest rate swap agreements, respectively) and will pay a variable rate based on LIBOR plus a percentage that varies with each agreement. As of December 31, 20082009 and 2007,2008, the aggregate fair value of our interest rate swaps included in “Other long-term assets, net” in our consolidated balance sheets was $15.3$8.6 million and $2.2$15.3 million, respectively.

The interest rate swap contracts qualify for the shortcut method of accounting prescribed by SFAS 133, “Accounting for Derivative Instruments and Hedging Activities,” as amended (SFAS 133).accounting. As a result, changes in the fair value of the swaps will completely offset the changes in the fair value of the underlying hedged debt. As of December 31, 20082009 and 2007,2008, the weighted average effective interest rate for the interest rate swaps was 3.0%2.3% and 6.1%3.0%, respectively.

Line of Credit Ratings

The following table reflects the outlook and ratings that have been assigned to the debt of our wholly owned subsidiaries as of December 31, 2008:

Standard &
Poor’s

Moody’s

Fitch

Outlook

NegativeNegativeNegative (a)

NuStar Logistics, L.P

BBB-Baa3BBB-

NuStar Pipeline Operating Partnership L.P

BBB-Baa3BBB-

(a)

On February 20, 2009, Fitch revised its outlook to stable from negative.

Notes Payable

Term Loan Agreement.    In March 2008, we closed on a $124.0 million term loan agreement (the Term Loan Agreement), all of which was used to fund a portion of our acquisition of the East Coast Asphalt Operations. The $124.0 million balance on the Term Loan Agreement was paid in full in April 2008 with the proceeds from our equity offering (see Equity Offerings section above).

Lines of Credit.As of December 31, 2008,2009, we had one short-term line of credit with an uncommitted borrowing capacity of up to $20.0 million. Please refer to Note 1211 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for a more detailed discussion on our short-term debt agreements.line of credit.

Long-Term Contractual Obligations

The following table presents our long-term contractual obligations and commitments and the related payments due, in total and by period, as of December 31, 2008:2009:

 

  

Payments Due by Period

      
  

Payments Due by Period

  

Thereafter

  

Total

  

2010

  

2011

  

2012

  

2013

  

2014

  

There-
after

  

Total

  

2009

  

2010

  

2011

  

2012

  

2013

    (Thousands of Dollars)
  (Thousands of Dollars)

Long-term debt maturities

  $713  $770  $832  $  936,941  $  480,902  $406,827  $  1,826,985  $770  $832  $909,942  $480,902  $67  $  406,200  $1,798,713

Interest payments

     105,827     105,770     105,708   94,611   42,596   151,764   606,276   89,804   89,742   79,501   41,597   27,220   100,150   428,014

Operating leases

   40,151   30,970   27,428   23,853   21,008   153,403   296,813   51,734   60,808   44,415   41,453   37,760   187,638   423,808

Purchase obligations:

                            

Crude oil

   901,995   901,995   901,995   901,995   901,995   1,127,494   5,637,469   1,943,668   1,943,668   1,943,668   1,943,668   1,943,670   485,917   10,204,259

Other purchase obligations

   64,224   20,521   16,520   1,398   962   743   104,368   23,561   18,329   2,197   1,036   744   -   45,867

We have long-termLong-term debt obligations and interest payments due under our senior notes, our 2007 Revolving Credit Agreement, our UK Term Loan, our Gulf Opportunity Zone Revenue Bonds and our Port of Corpus Christi Note Payable. Amountsmaturities in the table represent our scheduled future maturities of long-term debt principal for the periods indicated. The interest paymentpayments calculated for our 2007 Revolving Credit Agreement isvariable-rate debt are based on the outstanding borrowings as of December 31, 20082009 and the weighted-average interest rate paid for the year ended December 31, 2008.2009. The interest payments on our fixed-rate debt are based on the stated interest rates, the outstanding balances as of December 31, 2009 and interest payment dates.

Our operating leases consist primarily of leases for tugtugs and barges utilized at our St. Eustatius facility,and Point Tupper facilities, leases related to our acquisition of the East Coast Asphalt Operationsasphalt and fuels marketing segment for tugs and barges and storage capacity at third-party terminals and land leases at various terminal facilities. We are a party to a ten-year lease commitment of approximately $89.0 million for tugs and barges to be utilized at our St. Eustatius facility.

A purchase obligation is an enforceable and legally binding agreement to purchase goods or services that specifies significant terms, including (i) fixed or minimum quantities to be purchased, (ii) fixed, minimum or variable price provisions, and (iii) the approximate timing of the transaction.

Our crude oil purchase obligations result from a crude supply agreement (CSA) we entered into simultaneously with the acquisition of the East Coast Asphalt Operations. Under the CSA, we committed to purchase an annual average of 75,000 barrels per day of crude oil over a minimum seven-year period from PDVSA. The value of this commitment fluctuates according to a market-based pricing formula using published market indices, subject to adjustment based on the price of Mexican Maya crude. We estimated the value ofannual payments due under the crude oil purchase obligationCSA based on market prices as of December 31, 2008.2009.

In recent months,Environmental, Health and Safety

We are subject to extensive federal, state and local environmental and safety laws and regulations, including those relating to the Organizationdischarge of materials into the environment, waste management, pollution prevention measures, pipeline integrity and operator qualifications, among others. Because more stringent environmental and safety laws and regulations are continuously being enacted or proposed, the level of future expenditures required for environmental, health and safety matters is expected to increase.

The balance of and changes in our accruals for environmental matters as of and for the years ended December 31, 2009 and 2008 are included in Note 12 of Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplemental Data.” We believe that we have adequately accrued for our environmental exposures.

Contingencies

We are subject to certain loss contingencies, the outcomes of which could have an adverse effect on our cash flows and results of operations, as further disclosed in Note 13 of the Petroleum Exporting Countries announced its intentionNotes to reduce crude oil production in response to dramatically lower demand for refined products. As a result, we received notice in January 2009 that our scheduled deliveries of Boscan crude oil would be reduced by 600,000 barrels in February and March from the amounts specified in our crude supply agreement with PDVSA. To date, we have replaced the volumes lost from PDVSA with alternative grades of crude oil purchased on the spot market. We have not received notification of any further supply reductions from PDVSA.

We have other purchase obligations mainly related to the purchase of petroleum products for resale to our customers.Consolidated Financial Statements.

Related Party TransactionsRELATED PARTY TRANSACTIONS

Our operations are managed by the general partner of our general partner, NuStar GP, LLC. The employees of NuStar GP, LLC perform services for our U.S. operations. We reimburse NuStar GP, LLC for all costs related to its employees, other than costs associated with NuStar GP Holdings under the services agreement described below and in Note 1816 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data”.Data.” We had a payable of $3.4$10.6 million and a receivable of $0.8$3.4 million, as of December 31, 20082009 and 2007,2008, respectively, with both amounts representing payroll and benefit plan costs, net of payments made by us. We also had a long-term payable as of December 31, 2009 and 2008 of $7.7 million and 2007 of $6.6 million, and $5.7 million, respectively, to NuStar GP, LLC related to amounts payable for retiree medical benefits and other post-employment benefits.

Prior to December 22, 2006, Valero Energy controlled our general partner. We have transactions with Valero Energy for pipeline tariff, terminalling fee and crude oil storage tank fee revenues, certain employee costs, insurance costs, administrative costs and lease expense, which were reported as related party transactions in the consolidated statements of income. Due to Valero Energy’s sale of its interest in NuStar GP Holdings on December 22, 2006, we ceased reporting transactions with Valero Energy as related party transactions subsequent to that date.

The following table summarizes information pertaining to related party transactions with NuStar GP, LLC for the years ended December 31, 2008 and 2007 and with Valero Energy for the year ended December 31, 2006:LLC:

 

   

Year Ended December 31,

   

2008

  

2007

  

2006

   (Thousands of Dollars)

Revenues

  $-  $-  $  260,980

Operating expenses

     115,291     93,211   94,587

General and administrative expenses

   44,988   37,702   32,183

Agreements with NuStar GP Holdings

   

Year Ended December 31,

    
   

2009

  

2008

  

2007

  
   (Thousands of Dollars)  

Operating expenses

  $  124,827  $  115,291  $  93,211  

General and administrative expenses

   58,878   44,988   37,702  

On April 24, 2008, the boards of directors of NuStar GP, LLC and NuStar GP Holdings approved (i) the termination of the administration agreement, dated July 16, 2006, between NuStar GP Holdings and NuStar GP, LLC and (ii) the adoption of a services agreement between NuStar GP, LLC and NuStar Energy (the GP Services Agreement). On July 19, 2006, we entered into a non-compete agreement with NuStar GP Holdings, Riverwalk Logistics, L.P., and NuStar GP, LLC effective on December 22, 2006 (the Non-Compete Agreement). Please refer to Note 1816 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for a more detailed discussion of agreements with NuStar GP Holdings.

Agreements with Valero Energy

We are a party to a number of agreements with Valero Energy, which was a related party during 2006, that govern the required services provided to and received from Valero Energy. Most of the operating agreements include adjustment provisions, which allow us to increase the handling, storage and throughput fees we charge to Valero Energy based on a consumer price index. In addition, we review our pipeline tariffs, which are adjusted annually based on an inflation index and may also be adjusted to take into consideration additional costs incurred to provide the transportation services. Please refer to Note 18 of the Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data” for a more detailed discussion of agreements with Valero Energy.

Services Agreement.    Prior to our separation from Valero Energy, the employees of NuStar GP, LLC were provided to us under the terms of various services agreements between us and Valero Energy. Although Valero Energy no longer provided employees to work directly on our behalf, Valero Energy continued to provide certain services to us under the terms of a services agreement dated December 22, 2006 (the 2007 Services Agreement). On April 16, 2007, Valero Energy exercised its option to terminate the 2007 Services Agreement and paid us a termination fee of $13.0 million in May 2007 in accordance with the terms of the 2007 Services Agreement.

Omnibus Agreement.    On March 31, 2006, we entered into an amended and restated omnibus agreement (the 2006 Omnibus Agreement) with Valero Energy, NuStar GP, LLC, Riverwalk Logistics, L.P. and NuStar Logistics. The 2006 Omnibus Agreement governed potential competition between Valero Energy and us until the closing of NuStar GP Holdings’ second offering on December 2, 2006, when Valero Energy ceased to own 20% or more of us, and Valero Energy agreed to indemnify us for certain environmental liabilities.

Operating Agreements.    The following are the primary operating agreements with Valero Energy:

Crude Oil Storage Tank Agreements relating to the Corpus Christi West, Texas City and Benicia refineries;

South Texas Pipelines and Terminals Agreements related to certain pipelines and terminals acquired from Valero Energy in March 2003; and

St. James Terminalling Agreement.

Environmental, Health and Safety

We are subject to extensive federal, state and local environmental and safety laws and regulations, including those relating to the discharge of materials into the environment, waste management, pollution prevention measures, pipeline integrity and operator qualifications, among others. Because more stringent new environmental and safety laws and regulations are continuously being enacted or proposed, the level of future expenditures required for environmental, health and safety matters is expected to increase.

The balance of and changes in our accruals for environmental matters as of and for the years ended December 31, 2008 and 2007 are included in Note 14 of Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplemental Data.” We believe that we have adequately accrued for our environmental exposures.

Contingencies

We are subject to certain loss contingencies, the outcome of which could have an adverse effect on our cash flows and results of operations, as further disclosed in Note 15 of the Notes to Consolidated Financial Statements.

CRITICAL ACCOUNTING POLICIES

The preparation of financial statements in accordance with United States generally accepted accounting principles requires management to select accounting policies and to make estimates and assumptions related thereto that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates. The accounting policies below are considered critical due to judgments made by management and the sensitivity of these estimates to deviations of actual results from management'smanagement’s assumptions. The critical accounting policies should be read in conjunction with Note 2 of Notes to the Consolidated Financial Statements in Item 8. “Financial Statements and Supplemental Data,” which summarizes our significant accounting policies.

Depreciation

We calculate depreciation expense using the straight-line method over the estimated useful lives of our property, plant and equipment. Because ofDue to the expected long useful lives of theour property, plant and equipment, we depreciate our property, plant and equipment over periods ranging from 10 years to 40 years. Changes in the estimated useful lives of theour property, plant and equipment could have a material adverse effect on our results of operations.

Impairment of Long-Lived Assets and Goodwill

We test long-lived assets for recoverability whenever events or changes in circumstances indicate that the carrying amount of the asset may not be recoverable. Goodwill must be tested for impairment annually or more frequently if events or changes in circumstances indicate that the related asset might be impaired. An impairment loss should be recognized only if the carrying amount of the asset/goodwill is not recoverable and exceeds its fair value. The goodwill impairment test is performed for each reporting unit to which goodwill has been allocated, consisting of the following:

crude oil pipelines;

refined product pipelines;

refined product terminals, excluding our St. Eustatius and Point Tupper facilities;

St. Eustatius and Point Tupper terminal operations;

bunkering activity at our St. Eustatius and Point Tupper facilities; and

asphalt operations.

In order to test for recoverability, management must make estimates of projected cash flows related to the asset which include, but are not limited to, assumptions about the use or disposition of the asset, estimated remaining life of the asset, and future expenditures necessary to maintain the asset’s existing service potential. In order to determine fair value, management must make certain estimates and assumptions including, among other things, an assessment of market conditions, projected cash flows, investment rates, interest/equity rates and growth rates, that could significantly impact the fair value of the long-lived asset or goodwill. Due to the subjectivity of the assumptions used to test for recoverability and to determine fair value, significant impairment charges could result in the future, thus affecting our future reported net income.

Asset Retirement Obligations

We record a liability, which is referred to as an asset retirement obligation, at fair value for the estimated cost to retire a tangible long-lived asset at the time we incur that liability, which is generally when the asset is purchased, constructed or leased. We record a liability for asset retirement obligations when we have a legal obligation to incur costs to retire the asset and when a reasonable estimate of the fair value of the obligation can be made. If a reasonable estimate cannot be made at the time the liability is incurred, we record the liability when sufficient information is available to estimate the fair value.

We have asset retirement obligations with respectregard to certain of our assets due tothat have various legal obligations to clean and/or dispose of those assets at the time they are retired. However, these assets can be used for extended and indeterminate periodperiods of time as long as they are properly maintained and/or upgraded. It is our practice and current intent to maintain

our assets and continue making improvements to those assets based on technological advances. As a result, we believe that our assets have indeterminate lives for purposes of estimating asset retirement obligations because dates or ranges of dates upon which we would retire these assets cannot reasonably be estimated at this time. When a date or range of dates can reasonably be estimated for the retirement of any asset, we estimate the cost of performing the retirement activities and record a liability for the fair value of that cost using established present value techniques.

We also have legal obligations in the form of leases and right-of-way agreements, which require us to remove certain of our assets upon termination of the agreement. However, these lease or right-of-way agreements generally contain automatic renewal provisions that extend our rights indefinitely or we have other legal means available to extend our rights. We have recorded a liability of approximately $0.6 million and $0.8 million as of December 31, 20082009 and 2007, respectively,2008, which is included in “Other long-term liabilities” in our consolidated balance sheets, for conditional asset retirement obligations related to the retirement of terminal assets with lease and right-of-way agreements.

Environmental Reserve

Environmental remediation costs are expensed and an associated accrual established when site restoration and environmental remediation and cleanup obligations are either known or considered probable and can be reasonably estimated. Accrued liabilities are based on estimates of probable undiscounted future costs over a 20-year time period using currently available technology and applying current regulations, as well as our own internal environmental policies. The environmental liabilities have not been reduced by possible recoveries from third parties. Environmental costs include initial site surveys, costs for remediation and restoration and ongoing monitoring costs, as well as fines, damages and other costs, when estimable. Adjustments to initial estimates are recorded, from time to time, to reflect changing circumstances and estimates based upon additional information developed in subsequent periods. We believe that we have adequately accrued for our environmental exposures.

Contingencies

We accrue for costs relating to litigation, claims and other contingent matters, including tax contingencies, when such liabilities become probable and reasonably estimable. Such estimates may be based on advice from third parties or on management’s judgment, as appropriate. Due to the inherent uncertainty of litigation, actual amounts paid may differ from amounts estimated, and such differences will be charged to income in the period when final determination is made.

Derivative Financial Instruments

We are party to certain interest rate swap agreements for the purpose of hedging the interest rate risk associated with a portion of our fixed-rate senior notes. We account for the interest rate swaps as fair value hedges and recognize the fair value of each interest rate swap in the consolidated balance sheet as either an asset or liability. The interest rate swap contracts qualify for the shortcut method of accounting prescribed by SFAS 133. As a result, changes in the fair value of the derivatives will completely offset the changes in the fair value of the underlying hedged debt.

Since the operations of our marketing segment expose us to commodity price risk, we enter into derivatives instruments to mitigate the effect of commodity price fluctuations. The derivative instruments we use consist primarily of futures contracts and swaps traded on the NYMEX.

Derivative instruments designated and qualifying as fair value hedges under Statement of Financial Accounting Standards No. 133 (SFAS 133) are recorded in the consolidated balance sheet at fair value with mark-to-market adjustments recorded in cost of sales. The offsetting gain or loss on the associated hedged physical inventory is recognized concurrently in cost of sales. We record derivative instruments that do not qualify for hedge accounting under SFAS 133 in the consolidated balance sheet at fair value with mark-to-market adjustments recorded in cost of sales. The market fluctuations in inventory are not recognized until the physical sale takes place. Fair value is based on quoted market prices.

On a limited basis, we also enter into derivative commodity instruments based on our analysis of market conditions in order to profit from market fluctuations. These derivative instruments are financial positions entered into without underlying physical inventory and are not considered hedges. We record these derivatives in the consolidated balance sheet at fair value with mark-to-market adjustments recorded in revenues.

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Interest Rate Risk

We manage our debt by considering various financing alternatives available in the market and we manage our exposure to changing interest rates principally through the use of a combination of fixed-rate debt and variable-rate debt. In addition, we utilize interest rate swap agreements to manage a portion of the exposure to changing interest rates by converting certain fixed-rate debt to variable-rate debt. Borrowings under the 2007 Revolving Credit Agreement expose us to increases in the benchmark interest rate.

The following table provides information about our long-term debt and interest rate derivative instruments, all of which are sensitive to changes in interest rates. For long-term debt, principal cash flows and related weighted-average interest rates by expected maturity dates are presented. For interest rate swaps, the table presents notional amounts and weighted-average interest rates by expected (contractual) maturity dates. Weighted-average variable rates are based on implied forward interest rates in the yield curve at the reporting date.

 

  December 31, 2008   December 31, 2009
  Expected Maturity Dates         

Expected Maturity Dates

   

Total

    

Fair
Value

  

2009

  

2010

  

2011

  

2012

  

2013

  

Thereafter

  

Total

  

Fair

Value

   

2010

   

2011

   

2012

   

2013

   

2014

   

There-

after

 
  (Thousands of Dollars, Except Interest Rates)   (Thousands of Dollars, Except Interest Rates)

Long-term Debt:

                                

Fixed rate

  $713  $770  $832  $  381,647  $  480,902  $  350,627  $  1,215,491  $  1,157,470 $  770   $  832   $  384,816   $  480,902   $  67   $  350,000   $  1,217,387   $  1,306,301

Average interest rate

   8.0%   8.0%   8.0%   7.4%   6.0%   7.7%   6.9%    8.0  8.0  7.4  6.0  8.0  7.7  6.9  

Variable rate

  $-  $-  $-  $  555,294  $-  $56,200   611,494  $611,494 $  -   $  -   $  525,126   $  -   $  -   $  56,200   $  581,326   $  551,072

Average interest rate

   -   -   -   1.9%   -   0.9%   1.8%    -    -    1.0  -    -    0.2  0.9  

Interest Rate Swaps Fixed to Variable:

                                

Notional amount

  $-  $-  $-  $60,000  $  107,500  $-  $167,500  $15,284 $  -   $  -   $  60,000   $  107,500   $  -   $  -   $  167,500   $  8,623

Average pay rate

   3.2%   3.9%   4.3%   4.5%   4.3%   -   4.0%    3.4  4.8  5.8  5.6  -    -    4.3  

Average receive rate

   6.3%   6.3%   6.3%   6.3%   6.1%   -   6.3%    6.3  6.3  6.3  6.1  -    -    6.3  
  December 31, 2007   December 31, 2008
  Expected Maturity Dates         

Expected Maturity Dates

   

Total

    

Fair
Value

  

2008

  

2009

  

2010

  

2011

  

2012

  

Thereafter

  

Total

  

Fair

Value

   

2009

   

2010

   

2011

   

2012

   

2013

   

There-

after

 
  (Thousands of Dollars, Except Interest Rates)   (Thousands of Dollars, Except Interest Rates)

Long-term Debt:

                                

Fixed rate

  $663  $713  $770  $832  $  392,527  $  482,163  $877,668  $927,234 $  713   $  770   $  832   $  381,647   $  480,902   $  350,627   $  1,215,491   $  1,157,470

Average interest rate

   8.0%   8.0%   8.0%   8.0%   7.4%   6.0%   6.6%    8.0  8.0  8.0  7.4  6.0  7.7  6.9  

Variable rate

  $-  $-  $-  $-  $  527,976  $-   527,976  $527,976 $  -   $  -   $  -   $  555,294   $  -   $  56,200   $  611,494   $  611,494

Average interest rate

   -   -   -   -   5.7%   -   5.7%    -    -    -    1.9  -    0.9  1.8  

Interest Rate Swaps Fixed to Variable:

                                

Notional amount

  $-  $-  $-  $-  $60,000  $  107,500  $167,500  $2,232 $  -   $  -   $  -   $  60,000   $  107,500   $  -   $  167,500   $  15,284

Average pay rate

   5.3%   5.6%   6.1%   6.4%   6.7%   6.5%   6.1%    3.2  3.9  4.3  4.5  4.3  -    4.0  

Average receive rate

   6.3%   6.3%   6.3%   6.3%   6.3%   6.1%   6.3%    6.3  6.3  6.3  6.3  6.1  -    6.3  

Commodity Price Risk

We are exposedSince the operations of our asphalt and fuels marketing segment expose us to commodity price risk, with respectwe enter into derivative instruments to our product inventories and related firm commitments to purchase and/or sell such inventories. We utilizemitigate the effect of commodity price fluctuations. The derivative instruments we use consist primarily of futures contracts and swaps traded on the NYMEXNYMEX. Please refer to manage our exposurederivative financial instruments accounting policy in Note 2 of Notes to changesConsolidated Financial Statements in the fair value of certain of our product inventoriesItem 8. “Financial Statements and related firm commitments.Supplemental Data” for further information.

We have a risk management committee that oversees our trading controls and procedures and certain aspects of commodity and trading risk management. Our risk management committee also approvesreviews all new commodity and trading risk management strategies in accordance with our Risk Management Policy, asrisk management policy, which was approved by our board of directors.

Derivative instruments designated and qualifying as fair value hedges under FASB Statement No. 133, “Accounting for Derivative Instruments and Hedging Activities,” as amended (Statement No. 133) (Fair Value Hedges) are recorded in the consolidated balance sheets as assets or liabilities at fair value, with related mark-to-market adjustments recorded in “Cost of product sales.” The offsetting gain or loss on the associated hedged physical inventory or firm commitment, together with the resulting hedge ineffectiveness, is recognized concurrently in “Cost of product sales.” We record derivative instruments that do not qualify for hedge accounting under Statement No. 133 (Economic Hedges) in the consolidated balance sheets as assets or liabilities at fair value with mark-to-market adjustments recorded in “Cost of product sales.” Fair value is based on quoted market prices.

From time to time, we also enter into derivative commodity instruments based on our analysis of market conditions in order to attempt to profit from market fluctuations. These derivative instruments are financial positions entered into without underlying physical inventory and are not considered hedges. We record these derivatives in the consolidated balance sheets as assets or liabilities at fair value with mark-to-market adjustments recorded in “Product sales.”

The following tables provide information about our derivative instruments, the fair value of which will fluctuate with changes in commodity prices:

 

  December 31, 2008   December 31, 2009  
  

Contract
Volumes

  

Weighted Average

  

Fair Value of
Current
Asset (Liability)

   

Contract
Volumes

  

Weighted Average

  

Fair Value of
Current
Asset (Liability)

 
  Pay Price  Receive Price     

Pay Price

  

Receive Price

   
  (Thousands
of Barrels)
        (Thousands of
Dollars)
   (Thousands
of Barrels)
        (Thousands of
Dollars)
 

Fair Value Hedges:

                  

Futures – short:

                  

(refined products)

  445   N/A  $43.88  $    (2,370)  1,184       N/A  $79.89    $(9,528  

Cash Flow Hedges:

          

Futures – short:

          

(refined products)

  230       N/A  $94.13     (240  

Economic Hedges:

                  

Futures – long:

                  

(crude oil and refined products)

  119  $39.92   N/A  654   454      $81.46   N/A     2,327    

Futures – short:

                  

(crude oil and refined products)

  754   N/A  $48.95  (3,131)  745       N/A  $72.90     (10,692  

Swaps – long:

          

(crude oil and refined products)

  200      $70.34   N/A     398    

Swaps – short:

          

(crude oil and refined products)

  600       N/A  $70.16     (1,316  
                      

Total fair value of open positions exposed to commodity price risk

        $(19,051  
             

Total fair value of open positions

        $    (4,847)
          

  December 31, 2007   December 31, 2008
  

Contract

Volumes

  

Weighted Average

  

Fair Value of
Current

Asset (Liability)

   

Contract
Volumes

  

Weighted Average

  

Fair Value of
Current
Asset (Liability)

  Pay Price  Receive Price     

Pay Price

  

Receive Price

  
  (Thousands
of Barrels)
        (Thousands of
Dollars)
   (Thousands
of Barrels)
        (Thousands of
Dollars)

Fair Value Hedges:

                 

Futures – long:

        

(refined products)

  68  $104.26   N/A  $         460 

Futures – short:

                 

(refined products)

  287   N/A  $103.78  (1,942)  445       N/A  $43.88    $(2,370 

Economic Hedges:

                 

Futures – long:

                 

(refined products)

  60  $104.44   N/A  392 

(crude oil and refined products)

  119      $39.92   N/A     654   

Futures – short:

                 

(crude oil and refined products)

  459   N/A  $99.01  (3,001)  754       N/A  $48.95     (3,131 
                     

Total fair value of open positions

        $      (4,091)

Total fair value of open positions exposed to commodity price risk

        $(4,847 
                     

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

Management’s Report on Internal Control over Financial Reporting

Our management is responsible for establishing and maintaining effective internal control over financial reporting as defined in Rule 13a-15(f) under the Securities Exchange Act of 1934. Our management assessed the effectiveness of NuStar Energy L.P’s internal control over financial reporting as of December 31, 2008.2009. In its evaluation, management used the criteria set forth by the Committee of Sponsoring Organization of the Treadway Commission (COSO) in Internal Control-Integrated Framework. Based on this assessment, management believes that, as of December 31, 2008,2009, our internal control over financial reporting was effective based on those criteria.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.

The effectiveness of internal control over financial reporting as of December 31, 20082009 has been audited by KPMG LLP, the independent registered public accounting firm who audited our consolidated financial statements included in this Form 10-K. KPMG’sKPMG LLP’s attestation on the effectiveness of our internal control over financial reporting appears on page 63.62.

Report of Independent Registered Public Accounting Firm

The Board of Directors of NuStar GP, LLC

and Unitholders of NuStar Energy L.P.:

We have audited the accompanying consolidated balance sheets of NuStar Energy L.P. and subsidiaries (a Delaware limited partnership) and subsidiaries (the Partnership) as of December 31, 20082009 and 2007,2008, and the related consolidated statements of income, partners’ equity and cash flows for each of the years in the three-year period ended December 31, 2008.2009. These consolidated financial statements are the responsibility of the Partnership’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of NuStar Energy L.P. and subsidiaries as of December 31, 20082009 and 2007,2008, and the results of itstheir operations and itstheir cash flows for each of the years in the three-year period ended December 31, 2008,2009, in conformity with U.S. generally accepted accounting principles.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), NuStar Energy L.P. and subsidiaries’ internal control over financial reporting as of December 31, 2008,2009, based on the criteria established in Internal Control - Control—Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated February 27, 200926, 2010 expressed an unqualified opinion on the effectiveness of the Partnership’s internal control over financial reporting.reporting.

/s/ KPMG LLP

/s/ KPMG LLP

San Antonio, Texas

February 26, 2010

February 27, 2009

Report of Independent Registered Public Accounting Firm

The Board of Directors of

NuStar GP, LLC

and Unitholders of NuStar Energy L.P.:

We have audited NuStar Energy L.P. and subsidiaries’ (a Delaware limited partnership) and subsidiaries’ (the Partnership)Partnership’s) internal control over financial reporting as of December 31, 2008,2009, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).The Partnership’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on the Partnership’s internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.deteriorate.

In our opinion, NuStar Energy L.P. and subsidiaries maintained, in all material respects, effective internal control over financial reporting as of December 31, 2008,2009, based on criteria established in Internal Control - Integrated Framework issued by COSO.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of NuStar Energy L.P. and subsidiaries as of December 31, 20082009 and 2007,2008, and the related consolidated statements of income, partners’ equity and cash flows for each of the years in the three-year period ended December 31, 2008,2009, and our report dated February 27, 200926, 2010 expressed an unqualified opinion on those consolidated financial statements.statements.

/s/ KPMG LLP

/s/ KPMG LLP

San Antonio, Texas

February 26, 2010

February 27, 2009

NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Thousands of Dollars, Except Unit Data)

 

  

December 31,

  

December 31,

 
  

2008

 

2007

  

2009

 

2008

 
Assets       

Current assets:

       

Cash and cash equivalents

  $45,375  $89,838  $  62,006   $  45,375  

Accounts receivable, net of allowance for doubtful accounts of $1,174 and $365 as of December 31, 2008 and 2007, respectively

   178,216   130,354 

Receivable from related party

   -   786 

Accounts receivable, net of allowance for doubtful accounts of $1,351 and $1,174 as of December 31, 2009 and 2008, respectively

  211,797    178,216  

Inventories

   220,574   88,532   377,230    220,574  

Other current assets

   42,321   37,624   83,686    42,321  
               

Total current assets

   486,486   347,134   734,719    486,486  
               

Property, plant and equipment, at cost

   3,507,573   2,944,116   3,721,904    3,507,573  

Accumulated depreciation and amortization

   (565,749)  (452,030)  (693,708  (565,749
               

Property, plant and equipment, net

   2,941,824   2,492,086   3,028,196    2,941,824  

Intangible assets, net

   51,704   47,762   44,127    51,704  

Goodwill

   806,330   785,019   807,742    806,330  

Investment in joint ventures

   68,813   80,366   68,728    68,813  

Deferred income tax asset

   12,427   10,622   13,893    12,427  

Other long-term assets, net

   92,013   20,098   77,268    92,013  
               

Total assets

  $  4,459,597  $  3,783,087  $  4,774,673   $  4,459,597  
               
Liabilities and Partners’ Equity       

Current liabilities:

       

Current portion of long-term debt

  $713  $663  $  770   $  713  

Accounts payable

   145,963   163,309   205,605    145,963  

Payable to related party

   3,441   -   10,639    3,441  

Notes payable

   22,120   -   20,000    22,120  

Accrued interest payable

   22,496   17,725   21,529    22,496  

Accrued liabilities

   37,454   47,189   64,651    37,454  

Taxes other than income taxes

   15,333   10,157 

Income taxes payable

   4,504   3,442 

Taxes other than income tax

  15,534    15,333  

Income tax payable

  26    4,504  
               

Total current liabilities

   252,024   242,485   338,754    252,024  
               

Long-term debt, less current portion

   1,872,015   1,445,626   1,828,993    1,872,015  

Long-term payable to related party

   6,645   5,684   7,663    6,645  

Deferred income tax liability

   27,370   34,196   26,909    27,370  

Other long-term liabilities

   94,546   60,264   87,386    94,546  

Commitments and contingencies (Note 15)

   

Commitments and contingencies (Note 13)

    

Partners’ equity:

       

Limited partners (54,460,549 and 49,409,749 common units outstanding as of December 31, 2008 and 2007, respectively)

   2,173,462   1,926,126 

Limited partners (60,210,549 and 54,460,549 common units outstanding as of December 31, 2009 and 2008, respectively)

  2,423,689    2,173,462  

General partner

   47,801   41,819   53,469    47,801  

Accumulated other comprehensive income

   (14,266)  26,887 

Accumulated other comprehensive income (loss)

  7,810    (14,266
               

Total partners’ equity

   2,206,997   1,994,832   2,484,968    2,206,997  
               

Total liabilities and partners’ equity

  $  4,459,597  $  3,783,087  $  4,774,673   $  4,459,597  
               

See Notes to Consolidated Financial Statements.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME

(Thousands of Dollars, Except Unit and Per Unit Data)

 

    

Year Ended December 31,

 
  

Year Ended December 31,

     

2009

    

2008

    

2007

 
  

2008

 

2007

 

2006

 

Revenues:

             

Services revenues:

    

Third parties

  $740,630  $696,623  $375,174 

Related party

   -   -   260,980 
          

Total services revenues

   740,630   696,623   636,154 

Services revenues

 $   745,349   $   740,630   $   696,623  

Product sales

   4,088,140   778,391   501,107    3,110,522     4,088,140     778,391  
                         

Total revenues

   4,828,770   1,475,014   1,137,261    3,855,871     4,828,770     1,475,014  
                         

Costs and expenses:

             

Cost of product sales

   3,864,310   742,972   466,276    2,883,187     3,864,310     742,972  

Operating expenses:

             

Third parties

   326,957   264,024   218,017    334,065     326,957     264,024  

Related party

   115,291   93,211   94,587    124,827     115,291     93,211  
                         

Total operating expenses

   442,248   357,235   312,604    458,892     442,248     357,235  

General and administrative expenses:

             

Third parties

   31,442   30,213   13,033    35,855     31,442     30,213  

Related party

   44,988   37,702   32,183    58,878     44,988     37,702  
                         

Total general and administrative expenses

   76,430   67,915   45,216    94,733     76,430     67,915  

Depreciation and amortization expense

   135,709   114,293   100,266    145,743     135,709     114,293  
                         

Total costs and expenses

   4,518,697   1,282,415   924,362    3,582,555     4,518,697     1,282,415  
                         

Operating income

   310,073   192,599   212,899    273,316     310,073     192,599  

Equity earnings from joint ventures

   8,030   6,833   5,882    9,615     8,030     6,833  

Interest expense, net

   (90,818)  (76,516)  (66,266)   (79,384   (90,818   (76,516

Other income, net

   37,739   38,830   3,252    31,859     37,739     38,830  
                         

Income from continuing operations before income tax expense

   265,024   161,746   155,767 

Income before income tax expense

   235,406     265,024     161,746  

Income tax expense

   11,006   11,448   5,861    10,531     11,006     11,448  
          

Income from continuing operations

   254,018   150,298   149,906 

Loss from discontinued operations, net of income tax

   -   -   (376)
          

Net income

   254,018   150,298   149,530 

Less net income applicable to general partner

   (29,350)  (21,063)  (16,910)
          

Net income applicable to limited partners

  $224,668  $129,235  $132,620 
          

Income (loss) per unit applicable to limited partners:

    

Continuing operations

  $4.22  $2.74  $2.84 

Discontinued operations

   -   -   (0.01)
                         

Net income

  $4.22  $2.74  $2.83  $   224,875   $   254,018   $   150,298  
                         

Weighted average number of basic units outstanding

   53,182,741   47,158,790   46,809,749 

Net income per unit applicable to limited partners
(Note 19)

 $   3.47   $   4.22   $   2.73  
                         

Weighted average limited partner units outstanding

   55,232,467     53,182,741     47,158,790  
               

See Notes to Consolidated Financial Statements.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Thousands of Dollars)

 

  

Year Ended December 31,

     

Year Ended December 31,

 
  

2008

 

2007

 

2006

     

2009

    

2008

    

2007

 

Cash Flows from Operating Activities:

             

Net income

  $254,018  $150,298  $149,530  $   224,875   $   254,018   $   150,298  

Adjustments to reconcile net income to net cash provided by operating activities:

             

Depreciation and amortization expense

   135,709   114,293   100,266    145,743     135,709     114,293  

Amortization of debt related items

   (6,447)  (5,516)  (5,210)   (7,122   (6,447   (5,516

Gain on sale or disposition of assets

   (26,456)  (8,356)  (388)   (21,322   (26,456   (8,356

Provision (benefit) for deferred income taxes

   37   276   (74)

(Benefit) provision for deferred income tax

   (2,037   37     276  

Equity earnings from joint ventures

   (8,030)  (6,833)  (5,969)   (9,615   (8,030   (6,833

Distributions of equity earnings from joint ventures

   2,835   544   5,155    9,700     2,835     544  

Changes in current assets and current liabilities (Note 22)

   133,017   (21,326)  10,695 

Changes in current assets and current liabilities (Note 20)

   (152,280   133,017     (21,326

Other, net

   498   (708)  (3,194)   (7,360   498     (708
                         

Net cash provided by operating activities

   485,181   222,672   250,811    180,582     485,181     222,672  
                         

Cash Flows from Investing Activities:

             

Reliability capital expenditures

   (55,669)  (40,333)  (33,952)   (44,951   (55,669   (40,333

Strategic and other capital expenditures

   (146,474)  (210,918)  (90,070)

Strategic capital expenditures

   (163,605   (146,474   (210,918

East Coast Asphalt Operations acquisition

   (803,184)  -   -    -     (803,184   -  

Other acquisitions

   (7,027)  -   (154,474)   -     (7,027   -  

Investment in other long-term assets

   -   (62)  (10,820)   (211   -     (62

Proceeds from sale or disposition of assets

   50,813   12,667   71,396    29,680     50,813     12,667  

Proceeds from insurance settlement

   5,000   250   3,661    11,382     5,000     250  

Other, net

   24   -   1,025    -     24     -  
                         

Net cash used in investing activities

   (956,517)  (238,396)  (213,234)   (167,705   (956,517   (238,396
                         

Cash Flows from Financing Activities:

             

Proceeds from long-term debt borrowings

   2,108,775   1,170,302   269,026    1,159,436     2,108,775     1,170,302  

Proceeds from short-term debt borrowings

   746,800   75,000   -    448,752     746,800     75,000  

Proceeds from senior note offering, net of issuance costs

   346,224   -   -    -     346,224     -  

Long-term debt repayments

   (2,025,784)  (1,077,975)  (83,510)   (1,190,247   (2,025,784   (1,077,975

Short-term debt repayments

   (736,037)  (82,353)  -    (450,872   (736,037   (82,353

Proceeds from issuance of common units, net of issuance costs

   236,215   143,083   -    288,761     236,215     143,083  

Contributions from general partner

   5,025   3,035   575    6,155     5,025     3,035  

Distributions to unitholders and general partner

   (241,940)  (197,333)  (183,290)   (263,896   (241,940   (197,333

Increase (decrease) in cash book overdrafts

   945   3,676   (6,305)

(Decrease) increase in cash book overdrafts

   (761   945     3,676  

Other, net

   (160)  (375)  (395)   -     (160   (375
                         

Net cash provided by (used in) financing activities

   440,063   37,060   (3,899)

Net cash (used in) provided by financing activities

   (2,672   440,063     37,060  
                         

Effect of foreign exchange rate changes on cash

   (13,190)  (336)  (894)   6,426     (13,190   (336

Net (decrease) increase in cash and cash equivalents

   (44,463)  21,000   32,784 

Net increase (decrease) in cash and cash equivalents

   16,631     (44,463   21,000  

Cash and cash equivalents as of the beginning of year

   89,838   68,838   36,054    45,375     89,838     68,838  
                         

Cash and cash equivalents as of the end of year

  $45,375  $89,838  $68,838  $   62,006   $   45,375   $   89,838  
                         

See Notes to Consolidated Financial Statements.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF PARTNERS’ EQUITY

Years Ended December 31, 2009, 2008 2007 and 20062007

(Thousands of Dollars, Except Unit Data)

 

   

General

Partner

  

Accumulated

Other

Comprehensive

Income (Loss)

  

Total

Partners’

Equity

            Accumulated     
 

Limited Partners

            Other    Total 
 

Common

 

Subordinated

   

Limited Partners

    General    Comprehensive    Partners’ 
 

Units

 

Amount

 

Units

 

Amount

   

Units

    

Amount

   

Partner

   

Income (Loss)

   

Equity

 

Balance as of January 1, 2006

  37,210,427 $  1,749,007  9,599,322  $114,127  $38,913  $(1,268) $  1,900,779 

Balance as of January 1, 2007

  46,809,749 $   1,830,047   $   38,815   $   6,819   $   1,875,681  

Net income

  -  123,180  -   9,440   16,910   -   149,530   -   129,235     21,063     -     150,298  

Other comprehensive income – foreign currency translation

  -  -  -   -   -   8,087   8,087 
                    

Total comprehensive income

  -  123,180  -   9,440   16,910   8,087   157,617 
                    

Cash distributions to partners

  -  (149,004) -   (16,703)  (17,583)  -   (183,290)

General partner contribution

  -  -  -   -   575   -   575 

Conversion of subordinated units to common units on May 8, 2006

  9,599,322  106,864  (9,599,322)  (106,864)  -   -   - 
                    

Balance as of December 31, 2006

  46,809,749  1,830,047  -   -   38,815   6,819   1,875,681 
                    

Net income

  -  129,235  -   -   21,063   -   150,298 

Other comprehensive income – foreign currency translation

  -  -  -   -   -   20,068   20,068 

Other comprehensive income:

              

Foreign currency translation

  -   -     -     20,068     20,068  
                                           

Total comprehensive income

  -  129,235  -   -   21,063   20,068   170,366   -   129,235     21,063     20,068     170,366  
                                           

Cash distributions to partners

  -  (176,239) -   -   (21,094)  -   (197,333)  -   (176,239   (21,094   -     (197,333

Issuance of common units in November 2007 and related contribution from general partner

  2,600,000  143,083  -   -   3,035   -   146,118   2,600,000   143,083     3,035     -     146,118  
                                           

Balance as of December 31, 2007

  49,409,749  1,926,126  -   -   41,819   26,887   1,994,832   49,409,749   1,926,126     41,819     26,887     1,994,832  
                                           

Net income

  -  224,668  -   -   29,350   -   254,018   -   224,668     29,350     -     254,018  

Other comprehensive loss – foreign currency translation

  -  -  -   -   -   (41,153)  (41,153)

Other comprehensive loss:

              

Foreign currency translation

  -   -     -     (41,153   (41,153
                                           

Total comprehensive income

  -  224,668  -   -   29,350   (41,153)  212,865 

Total comprehensive loss

  -   224,668     29,350     (41,153   212,865  
                                           

Cash distributions to partners

  -  (213,547) -   -   (28,393)  -   (241,940)  -   (213,547   (28,393   -     (241,940

Issuance of common units in April 2008 and related contribution from general partner

  5,050,800  236,215  -   -   5,025   -   241,240   5,050,800   236,215     5,025     -     241,240  
                                           

Balance as of December 31, 2008

 $54,460,549 $  2,173,462  -  $-  $47,801  $(14,266) $  2,206,997   54,460,549   2,173,462     47,801     (14,266   2,206,997  
                                           

Net income

  -   192,239     32,636     -     224,875  

Other comprehensive income (loss):

              

Foreign currency translation

  -   -     -     22,316     22,316  

Unrealized loss on cash flow hedges

  -   -     -     (240   (240
                       

Total comprehensive income

  -   192,239     32,636     22,076     246,951  
                       

Cash distributions to partners

  -   (230,773   (33,123   -     (263,896

Issuance of common units in November 2009 and related contribution from general partner

  5,750,000   288,761     6,155     -     294,916  
                       

Balance as of December 31, 2009

  60,210,549 $   2,423,689   $   53,469   $   7,810   $   2,484,968  
                       

See Notes to Consolidated Financial Statements.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Years Ended December 31, 2009, 2008 2007 and 20062007

1. ORGANIZATION AND OPERATIONS

Organization

NuStar Energy L.P. (NuStar Energy) (NYSE: NS) is engaged in the terminalling and storage of petroleum products, the transportation of petroleum products and anhydrous ammonia, and asphalt and fuels marketing. Unless otherwise indicated, the terms “NuStar Energy L.P.,” “the Partnership,” “we,” “our” and “us” are used in this report to refer to NuStar Energy L.P., to one or more of our consolidated subsidiaries or to all of them taken as a whole. NuStar GP Holdings, LLC (NuStar GP Holdings) (NYSE: NSH) wholly owns our general partner, Riverwalk Logistics, L.P., and owns a 20.5%an 18.7% total interest in us.us as of December 31, 2009.

Operations

We conduct our operations through our subsidiaries, primarily NuStar Logistics, L.P. (NuStar Logistics) and NuStar Pipeline Operating Partnership L.P. (NuPOP). We have three business segments: storage, transportation, and asphalt and fuels marketing.

Storage.We own refined product terminals in the United States, the NetherlandNetherlands Antilles, Canada, Mexico, the Netherlands and the United Kingdom providing approximately 61.2 million barrels of storage capacity and one crude oil storage facility providing approximately 4.866.2 million barrels of storage capacity. Our terminals in the United States provide storage and handling services on a fee basis for petroleum products, specialty chemicals and other liquids, including one that provides storage services for crude oil and other feedstocks. We also own 60 crude oil and intermediate feedstock storage tanks and related assets that store and deliver crude oil and intermediate feedstocks to Valero Energy Corporation’s (Valero Energy) refineries in California and Texas providingprovide an aggregate 12.5 million barrels of storage capacity.capacity to refineries in California and Texas.

Transportation.We own common carrier refined product pipelines in Texas, Oklahoma, Colorado, New Mexico, Kansas, Nebraska, Iowa, South Dakota, North Dakota and Minnesota covering approximately 5,6795,605 miles, consisting of the Central West System, the East Pipeline and the North Pipeline. The East and North Pipelines also include 21 terminals providing storage capacity of 4.6 million barrels, and the East Pipeline includes two tank farms providing storage capacity of 1.2 million barrels. In addition, we own a 2,000 mile anhydrous ammonia pipeline located in Louisiana, Arkansas, Missouri, Illinois, Indiana, Iowa and Nebraska. We also own 812 miles of crude oil pipelines in Texas, Oklahoma, Kansas, Colorado and Illinois, as well as associated crude oil storage facilities providing storage capacity of 1.9 million barrels in Texas and Oklahoma that are located along the crude oil pipelines. We charge tariffs on a per barrel basis for transporting refined products, crude oil and other feedstocks in our refined product and crude oil pipelines and on a per ton basis for transporting anhydrous ammonia in our ammonia pipeline.

Asphalt and Fuels Marketing.Our asphalt and fuels marketing segment includes our asphalt refining operations and our fuels marketing operations. We refine crude oil to produce asphalt and certain other refined products from our asphalt operations. Our asphalt operations include two asphalt refineries with a combined throughput capacity of 104,000 barrels per day and related terminal facilities.facilities providing storage capacity of 5.0 million barrels. Additionally, as part of our fuels marketing operations, we purchase gasoline and other refined petroleum products for resale.

The activities of the asphalt and fuels marketing segment expose us to the risk of fluctuations in commodity prices, which directlyhas a direct impact on the results of operations for the asphalt and fuels marketing segment. We enter into derivative contracts to mitigate the effect of commodity price fluctuations.

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Consolidation

The accompanying consolidated financial statements represent the consolidated operations of the Partnership and our subsidiaries. Inter-partnership balances and transactions have been eliminated in consolidation. The operations of certain pipelines and terminals in which we own an undivided interest are proportionately consolidated in the accompanying consolidated financial statements.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Use of Estimates

The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and accompanying notes. Actual results could differ from those estimates. On an

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

ongoing basis, management reviews their estimates based on currently available information. ChangesManagement may revise estimates due to changes in facts and circumstances may result in revised estimates.circumstances.

Cash and Cash Equivalents

Cash equivalents are all highly liquid investments with an original maturity of three months or less when acquired.

Accounts Receivable

Accounts receivable represent valid claims against non-affiliated customers for products sold or services rendered. We extend credit terms to certain customers after review of various credit indicators, including the customer’s credit rating. Outstanding customer receivable balances are regularly reviewed for possible non-payment indicators and allowances for doubtful accounts are recorded based upon management’s estimate of collectability at the time of their review.

Inventories

Inventories consist of crude oil and refined petroleum products. All inventories are valued at the lower of cost or market and cost is determined using the weighted-average cost method. Our inventory consists entirely of one end-product category, petroleum products, which we include in the asphalt and fuels marketing segment. Accordingly, we determine lower of cost or market adjustments on an aggregate basis.

Property, Plant and Equipment

We record additions to property, plant and equipment, including reliability and strategic capital expenditures, at cost.

Reliability capital expenditures representare capital expenditures to replace partially or fully depreciated assets to maintain the existing operating capacity of existing assets and extend their useful lives. Strategic capital expenditures representare capital expenditures to expand or upgrade the operating capacity, increase efficiency or increase the earnings potential of existing assets, whether through construction or acquisition.acquisition, along with certain capital expenditures related to support functions. Repair and maintenance costs 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.

Depreciation of property, plant and equipment is recorded on a straight-line basis over the estimated useful lives of the related assets. Gains or losses on sales or other dispositions of property are recorded in income and are reported in “Other income, net” in the consolidated statements of income. When property or equipment is retired or otherwise disposed of, the difference between the carrying value and the net proceeds is recognized in the year retired.

Goodwill and Intangible Assets

Goodwill representsis the excess of cost of an acquired entity over the fair value of assets acquired less liabilities assumed. Goodwill acquired in a business combination is not amortized and is tested for impairment annually or more frequently if events or changes in circumstances indicate the asset might be impaired. We use October 1 of each year asis our annual valuation date for the impairment test. Based on the results of the impairment tests performed as of October 1, 2009, 2008 2007 and 2006,2007, no impairment had occurred.

Intangible assets are recorded at cost and are assets that lack physical substance (excluding financial assets). Intangible assets with finite useful lives are amortized on a straight-line basis over three to 47 years.

Investment in Joint Ventures

We account for our investments in joint ventures in Skelly-Belvieu Pipeline Company, LLC and ST Linden Terminals, LLC using the equity method of accounting.

ST Linden Terminals, LLC. The 44-acre facility provides deep-water terminalling capabilities at New York Harbor and primarily stores petroleum products, including gasoline, jet fuel and fuel oils. As part of our acquisition of Kaneb Services LLC (KSL) and Kaneb Pipe Line Partners, L.P. (KPP, and, together with KSL, Kaneb) on July 1, 2005 (the Kaneb Acquisition), we acquired an investment in ST Linden Terminals, LLC (Linden). Linden is owned 50% by the Partnership and 50% by NIC Holding Corp. In connection with the Kaneb Acquisition, we recorded our investment in Linden at fair value, which exceeded our 50% share of its members’ equity. This excess totaled $43.9 million and $44.2 million as of December 31, 2009 and 2008, respectively, of which $8.0 million is being amortized into expense over the average life of the assets held by Linden, or 25 years. The remaining balance not amortized represents goodwill of Linden.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Skelly-Belvieu Pipeline Company. The Skelly-Belvieu Pipeline Company (Skelly-Belvieu) owns a liquefied petroleum gas pipeline that begins in Skellytown, Texas and extends to Mont Belvieu, Texas near Houston. On December 1, 2008, we agreed to dispose of our interest in Skelly-Belvieu. See Note 4. Acquisitions and Dispositions below for further discussion on Skelly-Belvieu.

Other Long-Term Assets

“Other long-term assets, net” primarily include the following:

asphalt tank heel inventory and linefill on our ammonia pipeline;pipeline linefill;

the fair value of our interest rate swap agreements;

deferred costs incurred in connection with acquiring a customer contract, which is amortized over the life of the contract;

deferred financing costs amortized over the life of the related debt obligation using the effective interest method;

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

deferred dry-docking costs incurred in connection with major maintenance activities on our marine vessels, which are amortized over the period of time estimated to lapse until the next dry-docking occurs; and

deferred refinery shutdown costs in connection with annual major maintenance on our asphalt production units, which are amortized based on units of production over the following year; and

the remaining funds held in trust related to the issuance of Gulf Opportunity Zone Revenue Bonds associated with our terminal in St. James, Louisiana.year.

Impairment of Long-Lived Assets

Long-livedWe review long-lived assets, including property, plant and equipment and investment in joint ventures, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. TheWe perform the evaluation of recoverability is performed using undiscounted estimated net cash flows generated by the related asset. If we deem an asset is deemed to be impaired, we determine the amount of impairment is determined as the amount by which the net carrying value exceeds discounted estimated net cash flows.its fair value. We believe that the carrying amounts of our long-lived assets as of December 31, 20082009 are recoverable.

Taxes Other than Income Taxes

Taxes other than income taxes include liabilities for ad valorem taxes, franchise taxes, sales and use taxes, excise fees and taxes and value added taxes.

Income Taxes

We are a limited partnership and generally are not subject to federal or state income taxes. Accordingly, theour taxable income or loss, of the Partnership, which may vary substantially from income or loss reported for financial reporting purposes, is generally included in the federal and state income tax returns of the individualour partners. For transfers of publicly held units subsequent to our initial public offering, we have made an election permitted by Section 754 of the Internal Revenue Code to adjust the common unit purchaser’s tax basis in our underlying assets to reflect the purchase price of the units. This results in an allocation of taxable income and expenses to the purchaser of the common units, including depreciation deductions and gains and losses on sales of assets, based upon the new unitholder’s purchase price for the common units.

We conduct certain of our operations through taxable wholly owned corporate subsidiaries. IncomeWe account for income taxes are accounted for underrelated to our taxable subsidiaries using the asset and liability method. Under this method, we recognize deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. DeferredWe measure deferred taxes are measured using enacted tax rates expected to apply to taxable income in the year those temporary differences are expected to be recovered or settled.

We recognize a tax position if it is more-likely-than-not that the tax position will be sustained, based on the technical merits of the position, upon examination. We record uncertain tax positions in the financial statements at the largest amount of benefit that is more-likely-than-not to be realized. We had no unrecognized tax benefits as of December 31, 2008 or December 31, 2007.2009 and 2008.

NuStar Energy or certain of its subsidiaries file income tax returns in the U.S. federal jurisdiction and various state and foreign jurisdictions. For U.S. federal and state purposes, tax years subject to examination are 20042005 through 20082009 and for our major non-U.S. jurisdictions, tax years subject to examination are 20022003 through 2008,2009, both according to standard statuestatute of limitations.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Asset Retirement Obligations

We record a liability for asset retirement obligations, at the fair value of the estimated costs to retire a tangible long-lived asset at the time we incur that liability, which is generally when the asset is purchased, constructed or leased, when we have a legal obligation to incur costs to retire the asset and when a reasonable estimate of the fair value of the obligation can be made. If a reasonable estimate cannot be made at the time the liability is incurred, we record the liability when sufficient information is available to estimate the fair value.

We have asset retirement obligations with respect to certain of our assets due to various legal obligations to clean and/or dispose of those assets at the time they are retired. However, these assets can be used for an extended and indeterminate period of time as long as they are properly maintained and/or upgraded. It is our practice and current intent to maintain our assets and continue making improvements to those assets based on technological advances. As a result, we believe

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

that our assets have indeterminate lives for purposes of estimating asset retirement obligations because dates or ranges of dates upon which we would retire these assets cannot reasonably be estimated at this time. When a date or range of dates can reasonably be estimated for the retirement of any asset, we estimate the costcosts of performing the retirement activities and record a liability for the fair value of that cost using established present value techniques.these costs.

We also have legal obligations in the form of leases and right-of-way agreements, which require us to remove certain of our assets upon termination of the agreement. However, these lease or right-of-way agreements generally contain automatic renewal provisions that extend our rights indefinitely or we have other legal means available to extend our rights. We have recorded a liability of approximately $0.6 million and $0.8 million as of December 31, 20082009 and 2007, respectively,2008, which is included in “Other long-term liabilities” in the consolidated balance sheets, for conditional asset retirement obligations related to the retirement of terminal assets with lease and right-of-way agreements.

Environmental Remediation Costs

Environmental remediation costs are expensed and an associated accrual established when site restoration and environmental remediation and cleanup obligations are either known or considered probable and can be reasonably estimated. These environmental obligations are based on estimates of probable undiscounted future costs over a 20-year time period using currently available technology and applying current regulations, as well as our own internal environmental policies. The environmental liabilities have not been reduced by possible recoveries from third parties. Environmental costs include initial site surveys, costs for remediation and restoration and ongoing monitoring costs, as well as fines, damages and other costs, when estimable. Adjustments to initial estimates are recorded, from time to time, to reflect changing circumstances and estimates based upon additional information developed in subsequent periods.

Product Imbalances

ProductWe incur product imbalances occur within the East Pipeline system as a result of variances in pipeline meter readings as product is measured into and out of the pipeline system and volume fluctuations within the pipelineEast Pipeline system due to pressure and temperature changes. We use quoted market prices as of the reporting date to value our assets and liabilities related to product imbalances by petroleum product at adjusted market prices as of the reporting date.imbalances. Product imbalance liabilities are included in “Accrued liabilities” and product imbalance assets are included in “Other current assets” in the consolidated balance sheets. In the fourth quarter of 2008, we adjusted the product imbalance asset, the net impact of which increased operating income by $4.0 million.

Revenue Recognition

Revenues for the storage segment include fees for tank storage agreements, whereby a customer agrees to pay for a certain amount of storage in a tank over a period of time (storage lease revenues), and throughput agreements, whereby a customer pays a fee per barrel for volumes moving through our terminals and tanks (throughput revenues). Our terminals also provide blending, handling and filtering services. Our facilities at Point Tupper and St. Eustatius also charge fees to provide ancillary services such as pilotage, tug assistance, line handling, launch service, emergency response services and other ship services. Storage lease revenues are recognized when services are provided to the customer. Throughput revenues are recognized as refined products are received in or delivered out of our terminal and as crude oil and certain other refinery feedstocks are received by the related refinery. Revenues for ancillary services are recognized as those services are provided.

Revenues for the transportation segment are derived from interstate and intrastate pipeline transportation of refined product, crude oil and anhydrous ammonia. Transportation revenues (based on pipeline tariffs) are recognized as the refined product, crude oil or anhydrous ammonia is delivered out of the pipelines.

Revenues from the sale of asphalt and other refined petroleum products, which are included in our asphalt and fuels marketing segment, are recognized when product is delivered to the customer and title and risk pass to the customer. Additionally,

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

the revenues of our asphalt and fuels marketing segment include the mark-to-market impact of certain derivative instruments that are part of our limited trading program.

We collect taxes on certain revenue transactions to be remitted to governmental authorities, which may include sales, use, value added and some excise taxes. These taxes are not included in revenue.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Income Allocation

Our net income for each quarterly reporting period is first allocated to the general partner in an amount equal to the general partner’s incentive distribution calculated based upon the declared distribution for the respective reporting period. We allocate the remaining net income among the limited and general partners in accordance with their respective 98% and 2% interests.

Net Income per Unit Applicable to Limited Partners

We have identified the general partner interest and the subordinated unitsincentive distribution rights (IDR) as participating securities and use the two-class method when calculating the net income per unit applicable to limited partners, which is based on the weighted-average number of common and subordinated units outstanding during the period. Net income

In 2008, the Financial Accounting Standards Board (FASB) provided additional guidance clarifying the application of the two-class method to calculate earnings per unit applicable tofor master limited partners is computed by dividing net income applicable to limited partners, after deductingpartnerships with IDR that are accounted for as equity interests. Under the general partner’s 2% interest and incentive distributions, by the weighted-average number ofnew guidance, effective January 1, 2009, a master limited partnership units outstanding. Basicmust allocate earnings to its IDR in the calculation of earnings per unit. The terms of our partnership agreement limit distributions to the IDR holders to the amount of available cash calculated for the period. As a result, IDR are not allocated undistributed earnings or distributions in excess of earnings, thus the effect of adopting the additional guidance was not significant to our calculation of earnings per unit. Previous periods have been restated to conform to this presentation.Basic and diluted net income per unit applicable to limited partners are the same becauseas we have no potentially dilutive securities outstanding. The amount of net income per unit allocated to subordinated units was equal to the amount allocated to the common units for the periods prior to the conversion of the subordinated units into common units in May 2006.

Comprehensive Income

Comprehensive income consists of net income and other gains and losses affecting partners’ equity that are excluded from net income, such as foreign currency translation adjustments.adjustments and mark-to-market adjustments on derivative instruments designated and qualifying as cash flow hedges.

Derivative Financial Instruments

We are a party to certain interest rate swap agreements for the purpose of hedging the interest rate risk associated with a portion of our fixed-rate senior notes. We account for the interest rate swaps as fair value hedges and recognize the fair value of each interest rate swap in the consolidated balance sheet as either an asset or liability. The interest rate swap contractsagreements qualify for the shortcut method of accounting prescribed by FASB Statement No. 133, “Accounting for Derivative Instruments and Hedging Activities,” as amended (Statement No. 133).accounting. As a result, changes in the fair value of the derivativesswaps completely offset the changes in the fair value of the underlying hedged debt.

We are exposed torecord commodity price risk with respect to our product inventories and related firm commitments to purchase and/or sell such inventories. We utilize futures contracts and swaps traded on the NYMEX to manage our exposure to changes in the fair value of certain of our product inventories and related firm commitments.

Derivativederivative instruments designated and qualifying as fair value hedges under Statement No. 133 (Fair Value Hedges) are recorded in the consolidated balance sheets as assets or liabilities at fair value with relatedbased on quoted market prices. We recognize mark-to-market adjustments recordedfor derivative instruments designated and qualifying as fair value hedges (Fair Value Hedges) and the related change in “Costthe fair value of product sales.” The offsetting gain or loss on the associated hedged physical inventory or firm commitment together withwithin “Cost of product sales.” For derivative instruments designated and qualifying as cash flow hedges (Cash Flow Hedges), we record the resultingeffective portion of mark-to-market adjustments as a component of “Accumulated other comprehensive income” until the underlying hedged forecasted transactions occur and are recognized in income. Any hedge ineffectiveness is recognized concurrentlyimmediately in “Cost of product sales.” We recordOnce a hedged transaction occurs, we reclassify the effective portion from “Accumulated other comprehensive income” to “Cost of product sales.” For derivative instruments that do not qualify for hedge accounting under Statement No. 133 (Economic Hedges) in, we record the consolidated balance sheets as assets or liabilities at fair value with mark-to-market adjustments recorded in “Cost of product sales.” Fair value is based on quoted market prices.

From time to time, we also enter into derivative commodity instruments based on our analysis of market conditions in order to attempt to profit from market fluctuations. These derivative instruments are financial positions entered into without underlying physical inventory and are not considered hedges. We record these derivatives in the consolidated balance sheets as assets or liabilities at fair value with mark-to-market adjustments recorded in “Product sales.”

All cash flows associated with our commodity derivative instruments are classified as operating cash flows in the Consolidated Statements of Cash Flows.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Operating Leases

We recognize rent expense on a straight-line basis over the lease term, including the impact of both scheduled rent increases and free or reduced rents (commonly referred to as “rent holidays”).

Unit-based Compensation

NuStar GP, LLC, a wholly owned subsidiary of NuStar GP Holdings, has adopted various long-term incentive plans, which provide the Compensation Committee of the Board of Directors of NuStar GP, LLC with the right to grant employees and directors of NuStar GP, LLC providing services to NuStar Energy the right to receive NS common units. NuStar GP, LLC accounts for awards of NS unit options and restricted units at fair value in accordance with Emerging Issues Task Force Issue No. 02-08, “Accounting for Options Granted to Employee in Unrestricted, Publicly Traded Shares of an Unrelated Entity” (EITF 02-08). EITF 02-08 requires a company that grants its employees equity of an entity

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

other than the employer to account for such awards as a derivative, whereby a liability for the award is recorded at inception. Subsequent changes in the fair value of the award are included in the determination of net income. NuStar GP, LLC determines the fair value of NS unit options using the Black-Scholes model at each reporting date. NuStar GP, LLC determines the fair value of NS restricted units using the market price of NS common units at each reporting date. NuStar GP, LLC records compensation expense each reporting period such that the cumulative compensation expense recordedrecognized equals the current fair value of the percentage of the award that has vested. NuStar GP, LLC records compensation expense related to NS unit options until such options are exercised, and compensation expense related to NS restricted units until the date of vesting.

NuStar GP Holdings has adopted a long-term incentive plan that provides the Compensation Committee of the Board of Directors of NuStar GP Holdings with the right to grant employees, consultants and directors of NuStar GP Holdings and its affiliates, including NuStar GP, LLC, rights to receive NuStar GP Holdings common units. NuStar GP Holdings accounts for awards of NSH restricted units and unit options granted to its directors or employees of NuStar GP, LLC at fair value in accordance with FASB Statement No. 123 (revised 2004), “Share-Based Payment” (Statement No. 123R).value. The fair value of NSH unit options is determined using the Black-Scholes model at the grant date, and the fair value of the NSH restricted unit equals the market price of NSH common units at the grant date. NuStar GP Holdings recognizes compensation expense for NSH restricted units and unit options ratably over the vesting period based on the fair value of the units at the grant date.

We reimburse our general partnerNuStar GP, LLC for the expenseexpenses resulting from NS and NSH awards to employees and directors of NuStar GP, LLC. We include such compensation expense in “General and administrative expenses” on the consolidated statements of income. We do not reimburse our general partner for the expense resulting from NSH awards to non-employee directors of NuStar GP Holdings.

Under these long-term incentive plans, certain awards provide that employees vest in the award when they retire or will continue to vest in the award after retirement over the nominal vesting period established in the award. Through 2005, weWe accounted for such awards granted through 2005 by recognizing compensation expense over the nominal vesting period. By analogy to the transition rules of Statement No. 123R and the Securities and Exchange Commission’s (SEC) amended Rule 4-01(a) of Regulation S-X, weWe changed our method of recognizing compensation expense to the non-substantive vesting period approach for any awards granted after January 1, 2006. Under the non-substantive vesting period approach, compensation expense is recognized immediately for awards granted to retirement-eligible employees or over the period from the grant date to the date retirement eligibility is achieved if that date is expected to occur during the nominal vesting period.

Margin Deposits

Margin deposits relate to our exchange-traded derivative contracts and generally vary based on changes in the value of the contracts. Margin deposits are included in “Other current assets” in the consolidated balance sheets.

New Accounting PronouncementsReclassifications

FASB Statement No. 141R.  In DecemberCertain previously reported amounts in the 2008 and 2007 consolidated financial statements have been reclassified to conform to the Financial Accounting Standards Board (FASB) issued Statement No. 141 (Revised 2007), “Business Combinations” (Statement No. 141R). Statement No. 141R will significantly change the accounting for business combinations. Under Statement No. 141R, an acquiring entity will be required to recognize all the assets acquired and liabilities assumed in a transaction at the acquisition-date fair value, subject to limited exceptions. Statement No. 141R will change the accounting treatment for certain specific items, such as acquisition costs, acquired contingent liabilities, restructuring costs, changes in deferred tax asset valuation allowances and other items. Statement No. 141R also includes a substantial number of new disclosure requirements. Statement No. 141R applies prospectively to business combinations for which the acquisition date is on or after the beginning of the first annual reporting period beginning on or after December 15, 2008. We adopted Statement No. 141R effective January 1, 2009.

FASB Statement No. 161.  In March 2008, the FASB issued Statement No. 161, “Disclosures about Derivative Instruments and Hedging Activities” (Statement No. 161). Statement No. 161 amends and expands the disclosure requirements under Statement No. 133. Statement No. 161 requires enhanced disclosures on how and why an entity uses derivative instruments, how derivative instruments and related hedged items are accounted for and their impact on an entity’s financial performance, financial position and cash flows. Statement No. 161 is effective January 1, 2009. Retrospective application for previous periods is encouraged but not required. We adopted Statement No. 161 effective January 1, 2009 and do not expect it to have a material impact on our disclosures.presentation.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

EITF 07-4.  In March 2008, the FASB ratified its consensus on EITF Issue No. 07-4, “Application of the Two-Class Method under FASB Statement No. 128, Earnings per Share, to Master Limited Partnerships” (EITF No. 07-4). EITF No. 07-4 applies to master limited partnerships with incentive distribution rights (IDRs) that are accounted for as equity interests. EITF 07-4 states that IDRs are participating securities under Statement No. 128 and should be allocated earnings in the calculation of earnings per share. This allocation of earnings would be limited to the amounts distributable to the IDR holders in accordance with the partnership agreement. Retrospective application for comparative periods presented is required. We adopted EITF No. 07-4 effective January 1, 2009 and do not expect it to materially affect our computation of earnings per unit.3. NEW ACCOUNTING PRONOUNCEMENTS

FASB Staff Position FAS 142-3Fair Value Measurements.  

In April 2008,January 2010, the FASB issued Staff Position FAS 142-3, “Determinationadditional guidance that requires new disclosures regarding significant transfers in and out of Level 1 and Level 2 fair value measurements and additional information on the Useful Liferoll forward of Intangible Assets” (FSP FAS 142-3). FSP FAS 142-3 amendsLevel 3 fair value measurements. This guidance also clarified the factors that shouldexisting provisions on determining the appropriate classes of assets and liabilities to be considered in developing renewal or extension assumptions used to determinereported and disclosures about the useful life of a recognized intangible asset under FASB Statement No. 142, “Goodwillvaluation techniques and Other Intangible Assets.” FSP FAS 142-3 improves the consistency between the useful life of a recognized intangible asset under Statement No. 142 and the period of expected cash flowsinputs used to measure the fair value of the asset under Statement No. 141R. FSP FAS 142-3for both recurring and nonrecurring fair value measurements. This additional guidance is effective for financial statements issuedinterim and annual periods beginning after December 15, 2009, with the exception of the new requirements in the Level 3 roll forward, which will be effective for fiscal years beginning after December 15, 2008, and interim periods within those fiscal years.2010. We adopted FSP FAS 142-3these provisions effective January 1, 20092010 and do not expect itthem to materially affecthave a material impact on our financial position or results of operations.disclosures.

FASB Staff Position FAS 157-3.  In October 2008,August 2009, the FASB issued Staff Position FAS 157-3, “Determiningclarified the Fair Valueguidance on the fair value measurement of liabilities for circumstances in which a Financial Asset When the Marketquoted price in an active market for That Asset is Not Active” (FSP FAS 157-3). FSP FAS 157-3 clarifies the application of Statement No. 157 in cases where a marketan identical liability is not active. FSP FAS 157-3 wasavailable. This guidance is effective upon issuancethe first reporting period after issuance. Accordingly, we adopted these provisions effective October 1, 2009, and they did not materially affect our financial position or results of operations.

ReclassificationsVariable Interest Entities

Certain previously reported amounts inIn June 2009, the 2007FASB amended certain requirements related to variable interest entities (VIEs), including the requirements for determining whether an entity is a VIE or the primary beneficiary of a VIE. In addition, the amended requirements include additional disclosures about an entity’s involvement with a VIE. These amended requirements become effective as of the beginning of a company’s first annual reporting period that begins after November 15, 2009 and 2006 consolidatedfor interim periods within that first annual reporting period. Accordingly, we will be required to comply with the amended requirements on January 1, 2010 and do not expect them to materially affect our financial statements have been reclassified to conform to the 2008 presentation.position or results of operations.

3.4. ACQUISITIONS AND DISPOSITIONS

CITGO Asphalt Refining Company Asphalt Operations and Assets

On March 20, 2008, we acquired CITGO Asphalt Refining Company’s asphalt operations and assets (the East Coast Asphalt Operations) for approximately $838.5$840.4 million. The East Coast Asphalt Operations include a 74,000 barrels-per-day (BPD) asphalt refinery in Paulsboro, New Jersey, a 30,000 BPD asphalt refinery in Savannah, Georgia and three asphalt terminals. The facilities locatedterminals in Paulsboro, New Jersey, Savannah, Georgia and Wilmington, North Carolina have storage capacities of 3.5 million barrels, 1.2 million barrels, and 0.2 million barrels, respectively.Carolina.

We funded the acquisition with proceeds from our common unit offerings in November 2007 and April 2008, related contributions from our general partner to maintain its 2% interest, proceeds from our issuance of $350.0 million of senior notes and borrowings under our revolving credit agreement. The results of operations for the refineries, including the two related terminals in Paulsboro and Savannah, as well as the associated marketing activities, are included in the asphalt and fuels marketing segment. The results of operations for the Wilmington terminal are included in the storage segment.

The acquisition of the East Coast Asphalt Operations complementscomplemented our existing asphalt marketing operations givesby giving us exposure to the largest asphalt market in the United States, diversifiesdiversifying our customer base and expandsexpanding our geographic presence.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

The acquisition of the East Coast Asphalt Operations was accounted for using the purchase method. The purchase price has been preliminarilywas allocated based on the estimated fair values of the individual assets acquired and liabilities assumed at the date of acquisition pending completion of an independent appraisal and other evaluations. In the fourth quarter, we adjusted our preliminary purchase price allocation.acquisition. The adjusted purchase price and preliminaryfinal purchase price allocation were as follows (in thousands):

 

Cash paid for the East Coast Asphalt Operations

  $ 801,686

Transaction costs

   1,498
    

Total cash paid

   803,184

Fair value of liabilities assumed

   35,307
    

Purchase price

  $838,491
    

Inventories

  $327,312

Other current assets

   1,439

Property, plant and equipment

   450,310

Goodwill

   20,201

Intangible assets

   11,510

Other long-term assets

   27,719
    

Purchase price allocation

  $838,491
    

Cash paid for the East Coast Asphalt Operations

$801,686

Transaction costs

1,498

Total cash paid

803,184

Fair value of liabilities assumed

37,238

Purchase price

$840,422

Inventories

$327,312

Other current assets

1,439

Property, plant and equipment

450,310

Goodwill

22,132

Intangible assets

11,510

Other long-term assets

27,719

Purchase price allocation

$840,422

The consolidated statements of income include the results of operations for the East Coast Asphalt Operations commencing on March 20, 2008. The unaudited pro forma financial information presented below combines the historical financial information for the East Coast Asphalt Operations and the Partnership for those periods. This information assumes that we:

completed the acquisition of the East Coast Asphalt Operations on January 1, 2007;

issued approximately 7.7 million common units for net proceeds of $379.3 million;

received a contribution from our general partner of approximately $8.0 million to maintain its 2% interest;

issued $350.0 million of 7.65% senior notes; and

borrowed approximately $69.0 million under our revolving credit agreement.

The following unaudited pro forma information is not necessarily indicative of the results of future operations:

 

  Year Ended December 31,
  

2008

 

2007

  (Thousands of Dollars,
Except Per Unit Data)

Revenues

 $   5,008,623 $   3,395,379

Operating income

   318,626   241,181

Net income

   254,539   168,028

Net income per unit applicable to limited partners

 $   4.13 $   2.64

St. James Crude Facility

On December 1, 2006, we acquired a crude oil storage and blending facility in St. James, Louisiana from Koch Supply and Trading, L.P. for approximately $141.7 million (the St. James Acquisition). The acquisition included 17 crude oil tanks with a total capacity of approximately 3.3 million barrels. Additionally, the facility has three docks with barge and ship access. The facility is located on the west bank of the Mississippi River approximately 60 miles west of New Orleans. We funded the acquisition with borrowings under our existing revolving credit agreement. The financial statements include the results of operations in the storage segment commencing on December 1, 2006.

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NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

The St. James Acquisition was accounted for using the purchase method. The purchase price and purchase price allocation were as follows (in thousands):

Cash paid for St. James Terminal

  $140,900

Transaction costs

   759
    

Total

  $  141,659
    

Current assets

  $53

Property and equipment

   126,258

Goodwill

   13,898

Intangible assets

   1,450
    

Total

  $141,659
    

Since the effect of the St. James Acquisition was not significant, we have not presented pro forma financial information for the year ended December 31, 2006 that gives effect to the St. James Acquisition as of January 1, 2006.

Capwood Pipeline

Effective January 1, 2006, we purchased a 23.77% interest in Capwood pipeline from Valero Energy for $12.8 million, which was paid from borrowings under our existing revolving credit agreement. The Capwood pipeline is a 57-mile crude oil pipeline that extends from Patoka, Illinois to Wood River, Illinois. Plains All-American Pipeline L.P., the operator of the Capwood pipeline, owns the remaining 76.23% interest. Our financial statements include the results of operations of our interest in the Capwood pipeline in the transportation segment commencing on January 1, 2006.

4. DISPOSITIONS

Sale of Investment in Skelly-Belvieu

On December 1, 2008, we agreed to dispose of our interest in the Skelly-Belvieu Pipeline Company, LLC (Skelly-Belvieu), which owns a liquefied petroleum gas pipeline in Texas, to Enterprise Products Operating LLC. See Note 10. Investment in Joint Ventures below for further discussion on our investments in joint ventures, including Skelly-Belvieu.

Sale of Australia and New Zealand Subsidiaries

On March 30, 2006, we sold our Australia and New Zealand subsidiaries to ANZ Terminals Pty. Ltd., for total We received proceeds of $70.1 million. This transaction included the sale of eight terminals with an aggregate storage capacity of approximately 1.1 million barrels. The results of operations for the Australia and New Zealand Subsidiaries for 2006 have been included in income from discontinued operations. Revenues and pre-tax income related to the Australia and New Zealand Subsidiaries, included in income from discontinued operations, were $5.0$36.0 million and $0.6recognized a gain of $18.9 million respectively, forin “Other income, net” in the year ended December 31, 2006. Additionally, the income from discontinued operations includes interest expenseconsolidated statements of approximately $0.8 million allocated to the Australia and New Zealand Subsidiaries for the year ended December 31, 2006, which was based upon the expected proceeds and the interest rate applicable to our debt.income.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

5. ALLOWANCE FOR DOUBTFUL ACCOUNTS

The changes in the allowance for doubtful accounts consisted of the following:

 

   

Year Ended December 31,

 
   

2008

  

2007

 
   (Thousands of Dollars) 

Balance as of beginning of year

  $     365  $  1,220 

Increase (decrease) in allowance

  973  (544)

Accounts charged against the allowance, net of recoveries

  (119) (324)

Foreign currency translation

  (45) 13 
       

Balance as of end of year

  $  1,174  $     365 
       

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

  

Year Ended December 31,

 
  

2009

  

2008

 
  (Thousands of Dollars) 

Balance as of beginning of year

 $   1,174   $   365  

Increase in allowance

   613     973  

Accounts charged against the allowance, net of recoveries

   (453   (119

Foreign currency translation

   17     (45
          

Balance as of end of year

 $   1,351   $   1,174  
          

6. INVENTORIES

Inventories consisted of the following:

 

 

December 31,

  

December 31,

 

2009

 

2008

  

2008

  

2007

 (Thousands of Dollars)
  (Thousands of Dollars)

Crude oil

  $14,912  $- $   74,250 $   14,912

Finished products

   205,662   88,532   302,980   205,662
              

Total

  $220,574  $  88,532 $   377,230 $   220,574
              

We purchase crude oil for the production of asphalt and other refined products. Our “Finished products” consist of asphalt, intermediates, gasoline, distillates and other petroleum products. We purchase gasoline, distillates and other petroleum products for resale.

7. OTHER CURRENT ASSETS

Other current assets consisted of the following:

 

  

December 31,

 

December 31,

  

2008

  

2007

 

2009

 

2008

  (Thousands of Dollars) (Thousands of Dollars)

Margin deposits

 $   38,650 $   -

Prepaid expenses

  $  13,882  $    7,506   16,845   13,882

Product advances

   13,045   -

Supplies

   10,617   9,402

Product imbalances

  11,502  13,597   2,096   11,502

Supplies inventory

  9,402  7,645

Derivatives, net

  3,610  8,601   -   3,610

Other

  3,925  275   2,433   3,925
              

Other current assets

  $  42,321  $  37,624 $   83,686 $   42,321
              

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

8. PROPERTY, PLANT AND EQUIPMENT

Property, plant and equipment, at cost, consisted of the following:

 

  

Estimated

Useful

Lives

      Estimated
Useful
Lives
 

December 31,

 
  

December 31,

   

2009

 

2008

 
  

2008

 

2007

   (Years) (Thousands of Dollars) 
  (Years)  (Thousands of Dollars) 

Land

  -  $114,323  $108,216   - $   118,040   $   114,323  

Land and leasehold improvements

  10 - 35   91,843   75,013   10 - 35   98,272     91,843  

Buildings

  15 - 40   46,663   39,789   15 - 40   56,992     46,663  

Pipelines, storage and terminals

  20 - 35   2,688,198   2,435,381   20 - 35   2,843,163     2,688,198  

Refining equipment

  20 - 35   412,549   -   20 - 35   424,220     412,549  

Rights-of-way

  20 - 40   102,336   102,217   20 - 40   101,587     102,336  

Construction in progress

  -   51,661   183,500   -   79,630     51,661  
                     

Total

     3,507,573   2,944,116      3,721,904     3,507,573  

Less accumulated depreciation and amortization

     (565,749)  (452,030)     (693,708   (565,749
                     

Property, plant and equipment, net

    $  2,941,824  $  2,492,086    $   3,028,196   $   2,941,824  
                     

Capitalized interest costs included in property, plant and equipment weretotaled $1.7 million, $5.1 million $6.0 million and $1.8$6.0 million for the years ended December 31, 2009, 2008 2007 and 2006,2007, respectively. Depreciation and amortization expense for property, plant and equipment wastotaled $136.1 million, $125.3 million $102.8 million and $92.5$102.8 million for the years ended December 31, 2009, 2008 and 2007, respectively.

9. INTANGIBLE ASSETS

Intangible assets consisted of the following:

  

December 31, 2009

  

December 31, 2008

 
  

Cost

 

Accumulated
Amortization

  

Cost

 

Accumulated
Amortization

 
  (Thousands of Dollars) 

Intangible assets subject to amortization:

           

Customer relationships

 $  70,410 $   (28,529 $   70,410 $   (21,476

Non-compete agreements

  1,515   (1,515   1,515   (1,464

Terminalling agreement

  1,000   (1,000   1,000   (667

Other

  2,809   (563   2,809   (423
                 

Total

 $  75,734 $   (31,607 $   75,734 $   (24,030
                 

All of our intangible assets are subject to amortization. Amortization expense for intangible assets was $7.6 million for each of the years ended December 31, 2009 and 2006, respectively.2008 and $7.2 million for the year ended December 31, 2007. The estimated aggregate amortization expense for the next five years is as follows:

  Amortization Expense  
   (Thousands of Dollars)  

2010

  $  7,193  

2011

      7,193  

2012

      7,103  

2013

      7,103  

2014

      7,103  

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

9. INTANGIBLE ASSETS

Intangible assets consisted of the following:

   

December 31, 2008

  

December 31, 2007

 
   

Cost

  

Accumulated
Amortization

  

Cost

  

Accumulated
Amortization

 
   (Thousands of Dollars) 

Intangible assets subject to amortization:

       

Customer relationships

  $70,410  $(21,476) $58,900  $(14,690)

Non-compete agreements

   1,515   (1,464)  1,765   (1,407)

Terminalling agreement

   1,000   (667)  1,000   (333)

Other

   2,809   (423)  2,809   (282)
                 

Total

  $75,734  $(24,030) $64,474  $(16,712)
                 

All of our intangible assets are subject to amortization. Amortization expense for intangible assets was $7.6 million, $7.2 million and $6.5 million for the years ended December 31, 2008, 2007 and 2006, respectively. The estimated aggregate amortization expense for the next five years is as follows:

   Amortization Expense
   (Thousands of Dollars)

2009

  $  7,567

2010

      7,183

2011

      7,183

2012

      7,093

2013

      7,093

10. INVESTMENT IN JOINT VENTURES

The following table presents summarized combined unaudited financial information related to our joint ventures as of December 31, 2008 and 2007 and for the years ended December 31, 2008, 2007 and 2006:

   

December 31,

   

2008 (a)

  

2007

   (Thousands of Dollars)

Balance Sheet Information:

    

Current assets

  $5,098  $10,387

Property, plant and equipment, net

   48,068   81,645
        

Total assets

  $53,166  $92,032
        

Current liabilities

  $3,997  $6,328

Members’ equity

   49,169   85,704
        

Total liabilities and members’ equity

  $53,166  $92,032
        

   

Year Ended December 31,

   

2008(a)

  

2007

  

2006

   (Thousands of Dollars)

Statement of Income Information:

      

Revenues

  $35,904  $31,502  $28,858

Net income

   15,635   13,528   12,355

Our share of net income (b)

   8,030   6,833   5,969

Our share of distributions

   2,835   544   5,268

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(a)

The balance sheet information above does not include Skelly-Belvieu, and the statement of income information includes Skelly-Belvieu through November 30, 2008.

(b)

Our share of net income shown in the table includes $0.1 million of income that is included in income from discontinued operations in the consolidated statement of income for the year ended December 31, 2006.

ST Linden Terminals, LLC

Formed in 1998, the 44-acre facility provides us with deep-water terminalling capabilities at New York Harbor and primarily stores petroleum products, including gasoline, jet fuel and fuel oils. As part of our acquisition of Kaneb Services LLC (KSL) and Kaneb Pipe Line Partners, L.P. (KPP, and, together with KSL, Kaneb) on July 1, 2005 (the Kaneb Acquisition), we acquired an investment in ST Linden Terminals, LLC (Linden). Linden is owned 50% by the Partnership and 50% by NIC Holding Corp. As part of the final allocation in 2006 of the purchase price of Kaneb, we recorded our investment in Linden at fair value. As a result, the carrying value of our investment in Linden exceeds our 50% share of its members’ equity. This excess totaled $44.2 million and $44.5 million as of December 31, 2008 and 2007, respectively, of which $8.0 million is being amortized into expense over the average life of the assets held by Linden, or 25 years. The remaining balance not amortized represents goodwill of Linden.

Skelly-Belvieu Pipeline Company

Formed in 1993, the Skelly-Belvieu Pipeline owns a liquefied petroleum gas pipeline that begins in Skellytown, Texas and extends to Mont Belvieu, Texas near Houston. On December 1, 2008, we agreed to dispose of our interest in Skelly-Belvieu. We received proceeds of $36.0 million and recognized a gain of $18.9 million in “Other income, net” in the consolidated statements of income.

11. ACCRUED LIABILITIES

Accrued liabilities consisted of the following:

 

  

December 31,

 

December 31,

  

2008

  

2007

 

2009

 

2008

  (Thousands of Dollars) (Thousands of Dollars)

Derivative liabilities

 $   30,788   -

Employee wages and benefit costs

  $  16,198  $  17,633   15,959   16,921

Unearned income

  2,125  2,401   4,714   2,322

Environmental costs

  3,994  5,435  ��2,798   3,994

Product imbalances

  2,193  10,513   676   2,193

Deferred insurance proceeds

  2,674  -   -   2,674

Other

  10,270  11,207   9,716   9,350
              

Accrued liabilities

  $  37,454  $  47,189 $   64,651 $   37,454
              

12. NOTES PAYABLE11. DEBT

Term Loan Agreement

In March 2008, we closed on a $124.0 million term loan agreement (the Term Loan Agreement), all of which was used to fund a portion of our acquisitionLong-term debt consisted of the East Coast Asphalt Operations. following:

  

December 31,

 
  

2009

  

2008

 
     (Thousands of Dollars) 

$1.2 billion revolving credit agreement

 $   525,126   $   555,294  

7.65% senior notes due 2018, net of unamortized discount of ($610) in 2009 and ($661) in 2008

   349,390     349,339  

6.05% senior notes due 2013, net of unamortized discount of ($209) in 2009 and ($273) in 2008 and a fair value adjustment of $5,885 in 2009 and $10,433 in 2008

   235,608     240,092  

6.875% senior notes due 2012, net of unamortized discount of ($80) in 2009 and ($111) in 2008 and a fair value adjustment of $2,738 in 2009 and $4,851 in 2008

   102,658     104,740  

7.75% senior notes due 2012, including a fair value adjustment of $16,148 in 2009 and $22,522 in 2008

   266,148     272,522  

5.875% senior notes due 2013, including a fair value adjustment of $7,178 in 2009 and $8,982 in 2008

   257,178     258,982  

UK term loan

   33,917     30,748  

Gulf Opportunity Zone revenue bonds

   56,200     56,200  

Port Authority of Corpus Christi note payable

   3,538     4,811  
          

Total debt

   1,829,763     1,872,728  

Less current portion

   (770   (713
          

Long-term debt, less current portion

 $   1,828,993   $   1,872,015  
          

The $124.0 million balance on the Term Loan Agreement was paid in full in April 2008 with the proceeds from our equity offering.long-term debt repayments are due as follows (in thousands):

Lines of Credit

During the year ended December 31, 2008, we had three short-term lines of credit with an uncommitted borrowing capacity of up to $65.0 million. We borrowed $622.8 million and repaid $602.8 million during the year ended December 31, 2008 under these uncommitted, short-term lines of credit based on current working capital needs. The interest rates and maturities on these uncommitted, short-term lines of credit vary and are determined at the time of the borrowing. The interest rates for these lines fluctuate with the Federal Funds rate.

As of December 31, 2008, we had one short-term line of credit with an uncommitted borrowing capacity of up to $20.0 million. Outstanding borrowings on this line of credit totaled $20.0 million as of December 31, 2008 at an interest rate of 2.1%. The weighted-average interest rate related to outstanding borrowings under this short-term line of credit during the year ended December 31, 2008 was 2.7%.

2010

 $   770

2011

   832

2012

   909,942

2013

   480,902

2014

   67

Thereafter

   406,200
    

Total repayments

   1,798,713

Net fair value adjustment and unamortized discount

   31,050
    

Total debt

 $   1,829,763
    

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

13. LONG-TERM DEBT

Long-term debt consisted of the following:

   

December 31,

 
   

2008

  

2007

 
   (Thousands of Dollars) 

$1.2 billion revolving credit agreement

  $555,294  $527,976 

7.65% senior notes due 2018, net of unamortized discount of ($661) in 2008

   349,339   - 

6.05% senior notes due 2013, net of unamortized discount of ($273) in 2008 and ($337) in 2007 and a fair value adjustment of $10,433 in 2008 and $1,646 in 2007

   240,092   231,241 

6.875% senior notes due 2012, net of unamortized discount of ($111) in 2008 and ($143) in 2007 and a fair value adjustment of $4,851 in 2008 and $586 in 2007

   104,740   100,444 

7.75% senior notes due 2012, including a fair value adjustment of $22,522 in 2008 and $28,225 in 2007

   272,522   278,225 

5.875% senior notes due 2013, including a fair value adjustment of $8,982 in 2008 and $10,668 in 2007

   258,982   260,668 

UK term loan

   30,748   41,628 

Gulf Opportunity Zone revenue bonds

   56,200   - 

Port Authority of Corpus Christi note payable

   4,811   6,107 
         

Total debt

   1,872,728   1,446,289 

Less current portion

   (713)  (663)
         

Long-term debt, less current portion

  $  1,872,015  $  1,445,626 
         

The long-term debt repayments are due as follows (in thousands):

2009

  $713

2010

   770

2011

   832

2012

   936,941

2013

   480,902

Thereafter

   406,827
    

Total repayments

   1,826,985

Net fair value adjustment and unamortized discount

   45,743
    

Total debt

  $  1,872,728
    

Interest payments totaled $95.3 million, $103.9 million $89.5 million and $75.0$89.5 million for the years ended December 31, 2009, 2008 2007 and 2006,2007, respectively.

NuStar Logistics’ 7.65%, 6.05% and 6.875% Senior Notes

On April 4, 2008, NuStar Logistics issuedThe $350.0 million of 7.65% senior notes under our $3.0 billion shelf registration statement for net proceeds of $346.2 million. The net proceeds were used to repay a portion of the outstanding principal balance under our revolving credit agreement described below. Themature in 2018, with interest on the 7.65% senior notes is payable semi-annually in arrears on April 15 and October 15 of each year beginning on October 15, 2008. The notes will mature on April 15, 2018.year. The interest rate payable on the notes is subject to adjustment if our debt rating is downgraded (or subsequently upgraded) by certain credit rating agencies.

The $229.9 million of 6.05% senior notes mature in 2013, with interest payable semi-annually in arrears on March 15 and September 15 of each year.

The $100.0 million of 6.875% senior notes mature in 2012, with interest payable semi-annually in arrears on January 15 and July 15 of each year.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

The 7.65%, 6.05% and the 6.875% senior notes do not have sinking fund requirements. These notes rank equally with existing senior unsecured indebtedness of NuStar Logistics and contain restrictions on NuStar Logistics’ ability to incur secured indebtedness unless the same security is also provided for the benefit of holders of the senior notes. In addition, the senior notes limit NuStar Logistics’ ability to incur indebtedness secured by certain liens and to engage in certain sale-leaseback transactions.

At the option of NuStar Logistics, the 6.05% and the 6.875% senior notes may be redeemed in whole or in part at any time at a redemption price, which includes a make-whole premium, plus accrued and unpaid interest to the redemption date. Those notes also include a change-in-control provision, which requires that (1) an investment-grade entity own, directly or indirectly, 51% of our general partner interests; and (2) we (or an investment-grade entity) own, directly or indirectly, all of the general partner and limited partner interests in NuStar Logistics.

Valero Energy’s December 22, 2006 sale of its remaining interests in NuStar GP Holdings, which does not have an investment grade rating, triggered the change-in-control provision, and NuStar Logistics offered to purchase the senior notes at a price equal to 100% of their outstanding principal balance plus accrued interest through the date of purchase. This offer expired on January 23, 2007, with approximately $20.1 million of the 6.05% senior notes tendered to us for repurchase. We retired the senior notes that were tendered with borrowings under our then-active $600 million revolving credit agreement on February 1, 2007. The retirement of those senior notes did not significantly affect either our financial position or results of operations.

NuPOP’s 7.75% and 5.875% Senior Notes

As a result of the Kaneb Acquisition, we assumed the outstanding senior notes issued by NuPOP, having an aggregate face value of $500.0 million, and an aggregate fair value of $555.0 million. We use the effective interest method to amortize the difference between the fair value and the face value of the senior notes as a reduction of interest expense over the remaining lives of the senior notes.

The senior notes were issued in two series, the first of which bears interest at 7.75% annually (due semi-annually on February 15 and August 15) and matures February 15, 2012. The second series bears interest at 5.875% annually (due on June 1 and December 1) and matures June 1, 2013.

The 7.75% and 5.875% senior notes do not contain sinking fund requirements. These notes contain restrictions on our ability to incur indebtedness secured by liens, to engage in certain sale-leaseback transactions, to engage in certain transactions with affiliates, as defined, and to utilize proceeds from the disposition of certain assets. At the option of NuPOP, the 7.75% and 5.875% senior notes may be redeemed in whole or in part at any time at a redemption price, which includes a make-whole premium, plus accrued and unpaid interest to the redemption date.

The senior notes issued by NuStar Logistics are fully and unconditionally guaranteed by NuStar Energy. In connection with the Kaneb Acquisition, NuStar Energy fully and unconditionally guaranteed the outstanding senior notes issued by NuPOP. Additionally, effective July 1, 2005, both NuStar Logistics and NuPOP fully and unconditionally guaranteed the outstanding senior notes of the other. NuPOP will be released from its guarantee of senior notes issued by NuStar Logistics when it no longer guarantees any obligations of NuStar Energy, or any of its subsidiaries, including NuStar Logistics, under any bank facility or public debt instrument.

2007 Revolving Credit Agreement

On December 10, 2007, NuStar Logistics replaced the existing $600 million revolving credit agreement with theis party to a $1.2 billion five-year revolving credit agreement (the 2007 Revolving Credit Agreement), which includes a Euro sub-limitthe ability to borrow up to the equivalent of $250 million.million in Euros. Obligations under the 2007 Revolving Credit Agreement are guaranteed by NuStar Energy and NuPOP. NuPOP will be released from its guarantee of the 2007 Revolving Credit Agreement when it no longer guarantees NuStar Logistics’ public debt instruments.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

The 2007 Revolving Credit Agreement bears interest, at our option, based on either an alternative base rate or a LIBOR based rate, which was 1.9%1.0% as of December 31, 2008.2009. The weighted-average interest rate related to borrowings under the 2007 Revolving Credit Agreement during the year ended December 31, 20082009 was 3.7%1.0%.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

The lenders under the 2007 Revolving Credit Agreement is diversified with 24 participating banks. However, the participating banks include Lehman Brothers Bank, FSB (LB Bank), a subsidiary of Lehman Brothers Holdings Inc. (Lehman), which filed for bankruptcy protection in October 2008. LB Bank’s participation in the 2007 Revolving Credit Agreement totaled $42.5 million, of which we had $17.0$5.0 million remained outstanding as of December 31, 2008.2009. As a result of Lehman’s bankruptcy filing in October 2008, LB Bank has elected not to fund its pro rata share of any future borrowings we request, which reducesreduced the total commitment under the 2007 Revolving Credit Agreement to approximately $1.2 billion. Excluding LB Bank’s participation, we had $610.7$624.6 million available for borrowing under the 2007 Revolving Credit Agreement as of December 31, 2008.2009. If other lenders under the 2007 Revolving Credit Agreement file for bankruptcy or experience severe financial hardship due to recent disruptions and steep declines in the global financial markets and generally severely tightening credit supply, they may not honor their pro rata share of our borrowing requests.

The 2007 Revolving Credit Agreement includes restrictive covenants, including a prohibition on distributions if any defaults, as defined in the agreements, exist or would result from the distribution. The 2007 Revolving Credit Agreement also requires us to maintain, as of the end of each rolling period, consisting of any period of four consecutive fiscal quarters, a consolidated debt coverage ratio (consolidated indebtedness to consolidated EBITDA, as defined in the 2007 Revolving Credit Agreement) not to exceed 5.00-to-1.00; provided, that if at any time NuStar Energy or any of its restricted subsidiaries consummates an acquisition for an aggregate net consideration of at least $100 million, then for two rolling periods, the last day of which immediately follows the day on which such acquisition is consummated, the maximum consolidated debt coverage ratio must not exceedwill increase to 5.50-to-1.00. Management believes thatThis consolidated debt coverage ratio may restrict the amount we are in compliance with all ratios and covenants ofcan borrow without exceeding the 2007 Revolving Credit Agreement asmaximum allowed limit to an amount less than the total amount available for borrowing. As of December 31, 2008.2009, the consolidated debt coverage ratio was 4.1x.

UK Term Loan

NuPOP’s UK subsidiary, NuStar Terminals Limited, formerly Kaneb Terminals Limited, is the borrower ofparty to the £21 million ($30.7 million and $41.6 million as of December 31, 2008 and 2007, respectively). This amended and restated term loan agreement (the UK Term Loan), which bears interest at 6.65% annually and matures on December 11, 2012.

On December 11, 2007, the UK Term Loan was amended to be consistent with the covenants and provisions of the 2007 Revolving Credit Agreement. Management believes that we are in compliance with all ratios and covenants of the UK Term Loan as of December 31, 2008.2009, which are substantially the same as the 2007 Revolving Credit Agreement.

Our other long-term debt obligations do not contain any financial covenants. However, a default under any of our debt instruments would be considered an event of default under all of our debt instruments.

Gulf Opportunity Zone Revenue Bonds

On June 26, 2008, the Parish of St. James, where our St. James, Louisiana, terminal is located, issued $56.2 million of Revenue Bonds (NuStar Logistics, L.P. Project) Series 2008 associated with theour St. James terminal expansion. The bonds mature on June 1, 2038. The interest rate is based on a weekly tax-exempt bond market interest rate and is paid monthly. The average interest rate was 2.3%0.5% for the year ended December 31, 2008.2009. Following the issuance, the proceeds were deposited with a trustee and will be disbursed to us upon our request for reimbursement of expenditures related to theour St. James terminal expansion. As of December 31, 2008,2009, we have received $52.3$55.5 million from the trustee, of which $0.6$3.2 million was used to pay bond issuance costs.received during the year ended December 31, 2009. As of December 31, 2008,2009, the remaining funds$0.7 milion in trust are included in “Other long-term assets, net,” and the $56.2 million obligation is included in “Long-term debt, less current portion” in our consolidated balance sheets.

NuStar Logistics is solely obligated to service the principal and interest payments associated with the bonds. One of the lenders under our 2007 Revolving Credit Agreement issued a letter of credit in the amount of $56.9 million on our behalf, to guarantee the payment of interest and principal on the bonds. This letter of credit ranks equally with existing senior unsecured indebtedness of NuStar Logistics and was issued under our 2007 Revolving Credit Agreement.

Port Authority of Corpus Christi Note Payable

The proceeds from the original $12.0 million note payable due to the Port of Corpus Christi Authority of Nueces County, Texas (Port Authority of Corpus Christi) were used for the construction of a crude oil storage facility in Corpus Christi, Texas. The note payable is due in annual installments of $1.2 million through December 31, 2015 and is collateralized by the crude oil storage facility. Interest on the unpaid principal balance accrues at a rate of 8.0% per annum. The land on

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

which the crude oil storage facility was constructed is leased from the Port Authority of Corpus Christi. The wharfage and dockage fees paid to the Port Authority of Corpus Christi in connection with the use of the crude oil storage facility have exceeded certain limits per the terms of the note, which have accelerated the repayment of the unpaid principal balance.

NUSTAR ENERGY L.P. AND SUBSIDIARIESLine of Credit

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)As of December 31, 2009, we had one short-term line of credit with an uncommitted borrowing capacity of up to $20.0 million. The interest rate and maturity vary and are determined at the time of the borrowing. The interest rate fluctuates with the Federal Funds rate.

We borrowed and repaid $448.8 million during the year ended December 31, 2009 under this line of credit based on liquidity needs. Outstanding borrowings on this line of credit totaled $20.0 million as of December 31, 2009 at an interest rate of 2.4%. The weighted-average interest rate related to outstanding borrowings under this short-term line of credit during the year ended December 31, 2009 was 2.4%.

14.12. HEALTH, SAFETY AND ENVIRONMENTAL MATTERS

Our operations are subject to extensive federal, state and local environmental laws and regulations, including those relating to the discharge of materials into the environment, waste management, pollution prevention measures, pipeline integrity and operator qualifications, among others. Our operations are also subject to extensive federal and state health and safety laws and regulations, including those relating to pipeline safety. The principal environmental and safety risks associated with our operations relate to unauthorized emissions into the air, unauthorized releases into soil, surface water or groundwater, and personal injury and property damage. Compliance with these environmental and safety laws, regulations and permits increases our capital expenditures and our overall cost of business, and violations of these laws, regulations and/or permits can result in significant civil and criminal liabilities, injunctions or other penalties.

The pipelines in the Central West System, the East Pipeline, the North Pipeline and the Ammonia Pipeline are subject to federal regulation by one or more of the following governmental agencies or laws: the Federal Energy Regulatory Commission (the FERC), the Surface Transportation Board (the STB), the Department of Transportation (DOT), the Environmental Protection Agency (EPA), and the Homeland Security Act. Additionally, the operations and integrity of the pipelines are subject to the respective state jurisdictions along the route of the systems.

We have adopted policies, practices and procedures in the areas of pollution control, pipeline integrity, operator qualifications, public relations and education, product safety, process safety, occupational health and the handling, storage, use and disposal of hazardous materials that are designed to prevent material environmental or other damage, to ensure the safety of our pipelines, our employees, the public and the environment and to limit the financial liability that could result from such events. Future governmental action and regulatory initiatives could result in changes to expected operating permits and procedures, additional remedial actions or increased capital expenditures and operating costs that cannot be assessed with certainty at this time. In addition, contamination resulting from spills of petroleum products occurs within the industry. Risks of additional costs and liabilities are inherent within the industry, and there can be no assurances that significant costs and liabilities will not be incurred in the future.

Environmental and safety exposures and liabilities are difficult to assess and estimate due to unknown factors such as the timing and extent of remediation, the determination of our liability in proportion to other parties, improvements in cleanup technologies and the extent to which environmental and safety laws and regulations may change in the future. Although environmental and safety costs may have a significant impact on the results of operations for any single period, we believe that such costs will not have a material adverse effect on our financial position.

The balance of and changes in the accruals for environmental matters were as follows:

   

Year Ended December 31,

 
   

2008

  

2007

 
   (Thousands of Dollars) 

Balance as of beginning of year

  $11,124  $13,683 

Additions to accrual

   4,393   3,872 

Payments

   (4,877)  (6,474)

Foreign currency translation

   (370)  43 
         

Balance as of end of year

  $10,270  $11,124 
         

Accruals for environmental matters are included in the consolidated balance sheets as follows:

   

December 31,

   

2008

  

2007

   (Thousands of Dollars)

Accrued liabilities

  $      3,994  $      5,435

Other long-term liabilities

   6,276   5,689
        

Accruals for environmental matters

  $10,270  $11,124
        

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

The balance of and changes in the accruals for environmental matters were as follows:

  

Year Ended December 31,

 
  

2009

  

2008

 
  (Thousands of Dollars) 

Balance as of beginning of year

 $   10,270   $   11,124  

Additions to accrual

   2,248     4,393  

Payments

   (3,241   (4,877

Foreign currency translation

   107     (370
          

Balance as of end of year

 $   9,384   $   10,270  
          

Accruals for environmental matters are included in the consolidated balance sheets as follows:

  

December 31,

  

2009

 

2008

  (Thousands of Dollars)

Accrued liabilities

 $   2,798 $   3,994

Other long-term liabilities

   6,586   6,276
        

Accruals for environmental matters

 $   9,384 $   10,270
        

15.13. COMMITMENTS AND CONTINGENCIES

Contingencies

We have contingent liabilities resulting from various litigation, claims and commitments, the most significant of which are discussed below. We record accruals for loss contingencies when losses are considered probable and can be reasonably estimated. Legal fees associated with defending the Partnership in legal matters are expensed as incurred. As of December 31, 2008,2009, we have recorded $0.8accrued $0.5 million of accruals related to settled matters and $80.7$74.4 million of accruals for contingent losses. The actual payment of any amounts accruedamount that will ultimately be paid related to these matters may differ from the recorded accruals, and the timing of such payments ultimately made is uncertain.

Grace Energy Corporation Matter.In 1997, Grace Energy Corporation (Grace Energy) sued subsidiaries of Kaneb in Texas state court. The complaint sought recovery of the cost of remediation of fuel leaks in the 1970s from a pipeline that had once connected a former Grace Energy terminal with Otis Air Force Base in Massachusetts (Otis AFB). Grace Energy alleges the Otis AFB pipeline and related environmental liabilities had been transferred in 1978 to an entity that was part of Kaneb’s acquisition of Support Terminal Services, Inc. and its subsidiaries from Grace Energy in 1993. Kaneb contends that it did not acquire the Otis AFB pipeline and never assumed any responsibility for any associated environmental damage.

In 2000, the court entered final judgment that: (i) Grace Energy could not recover its own remediation costs of $3.5 million, (ii) Kaneb owned the Otis AFB pipeline and its related environmental liabilities and (iii) Grace Energy was awarded $1.8 million in attorney costs. Both Kaneb and Grace Energy appealed the final judgment of the trial court to the Texas Court of Appeals in Dallas. In 2001, Grace Energy filed a petition in bankruptcy, which created an automatic stay of actions against Grace Energy. In September 2008, Grace Energy filed its Joint Plan of Reorganization and Disclosure Statement. We have sought relief from the bankruptcy stay in order to pursue our appellate rights.

The Otis AFB is a part of a Superfund Site pursuant to the Comprehensive Environmental Response Compensation and Liability Act (CERCLA). The site contains a number of groundwater contamination plumes, two of which are allegedly associated with the Otis AFB pipeline. Relying on the final judgment of the Texas state court assigning ownership of the Otis AFB pipeline to Kaneb, the U.S. Department of Justice (the DOJ) advised Kaneb in 2001 that it intends to seek reimbursement from Kaneb for the remediation costs associated with the two plumes. In November 2008, the DOJ forwarded information to us indicating that the past and estimated future remediation expenses associated with one plume are $71.9 million. The DOJ has indicated that they will not seek recovery of remediation costs for the second plume. The

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

DOJ has not filed a lawsuit against us related to this matter, and we have not made any payments toward costs incurred by the DOJ. We are currently in settlement discussions with other potentially responsible parties and the DOJ and a change in our estimate of this liability may occur in the near term. However, any settlement agreement that is reached must be approved by multiple parties and requires the approval of the bankruptcy court and the federal district court. We cannot currently estimate when or if a settlement will be finalized.

Eres Matter. In August 2008, Eres N.V. (Eres) forwarded a demand for arbitration to CITGO Asphalt Refining Company (CARCO), CITGO Petroleum Corporation (CITGO), NuStar Asphalt Refining, LLC (NuStar Asphalt) and NuStar Marketing LLC (NuStar Marketing, and together with CARCO, CITGO and NuStar Asphalt, the Defendants) contending that the Defendants are in breach of a tanker voyage charter party agreement, dated November 2004, between Eres and CARCO (the Charter Agreement). The Charter Agreement provides for CARCO’s use of Eres’ vessels for the shipment of asphalt. Eres contends that NuStar Asphalt and/or NuStar Marketing (together, the NuStar Entities) assumed the Charter Agreement when NuStar Asphalt purchased the CARCO assets, and that the Defendants have failed to perform under the Charter Agreement since January 1, 2008. Eres seeks to compel the Defendants to arbitrate a breach of contract claim in which Eres values its damages at approximately $78.1 million. CITGO/CARCO hasalso contend that the NuStar Entities assumed the Eres contract and they have demanded that the NuStar Asphalt and NuStar MarketingEntities defend and indemnify itthem against Eres’ claims. Eres’ motion to compel arbitration and CITGO/CARCO’s indemnity claims and has filed a lawsuit in the Harris County District Court, Harris County, Texas, seeking to recover on its indemnity claim. This lawsuit has been removed and isare currently pending in the U.S. District Court for the Southern District of Texas. In connection with the demand for arbitration, Eres filed a complaint in the U.S. District Court for the Southern District of New York (SDNY) seeking to require the Defendants to arbitrate the dispute and seeking to attach the banking funds of CARCO and NuStar Asphalt (including cash, escrow funds, credits, debts, wire transfers, electronic funds transfers, accounts, letters of credit, freights and charter hire) within the SDNY in amounts of approximately $78.1 million pending resolution of arbitration between Eres and the Defendants. To date, no funds of NuStar Asphalt have been attached. We intend to vigorously defend against these claims.

Department of Justice Matter. In February 2008, the DOJ advised us that the EPA has requested that the DOJ initiate a lawsuit against usNuPOP for (a) failing to prepare adequate Facility Response Plans, as required by Section 311(j)(5) of the Clean Water Act, 33 U.S.C. §1321(j), for certain of our pipeline terminals located in Region VII, by August 30, 1994, and (b)

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

maintaining Spill Prevention, Control and Countermeasure Plans (SPCC) Plans at the terminal that deviate from the SPCC regulations, 40 C.F.R. §112.3. A Facility Response Plan is a plan for responding to a worst case discharge, and to a substantial threat of such a discharge, of oil or hazardous substances. The SPCC rule requires specific facilities to prepare, amend and implement plans to prevent, prepare and respond to oil discharges to navigable waters and adjoining shorelines. We are currently in settlement negotiations with the DOJ to resolve these matters.

EPA Investigation.Other. In November 2006, agents of the EPA presented a search warrant issued by a U.S. District Court at one of our terminals. Since then, we have been served with additional subpoenas. The search warrant and subpoenas all sought information regarding allegations of potential illegal conduct by us, certain of our subsidiaries and/or our employees concerning compliance with certain environmental and safety laws and regulations. We have cooperated fully with the U.S. Attorney and the EPA in producing documents in response to the subpoenas. Although the U.S. Attorney has indicated that they intend to seek criminal penalties and fines as a result of alleged violations of environmental laws at the terminal, we are currently in negotiations with the U.S. Attorney and the EPA to resolve this matter. There can be no assurances that the conclusion of the U.S. Attorney’s and the EPA’s investigation will not result in a determination that we violated applicable laws. If we are found to have violated such laws, we could be subject to fines, civil penalties and criminal penalties. A final determination that we violated applicable laws could, among other things, result in our debarment from future federal government contracts.

We are also a party to additional claims and legal proceedings arising in the ordinary course of business. Due to the inherent uncertainty of litigation, there can be no assurance that the resolution of any particular claim or proceeding would not have a material adverse effect on our results of operations, financial position or liquidity. It is possible that if one or more of the matters described above were decided against us, the effects could be material to our results of operations in the period in which we would be required to record or adjust the related liability and could also be material to our cash flows in the periods we would be required to pay such liability.

Commitments

Future minimum rental payments applicable to all noncancellable operating leases and purchase obligations as of December 31, 20082009 are as follows:

 

  

Payments Due by Period

        

Payments Due by Period

  

2009

  

2010

  

2011

  

2012

  

2013

  

There-
after

  

Total

  

2010

  

2011

  

2012

  

2013

  

2014

  

There-
after

  

Total

  (Thousands of Dollars)  (Thousands of Dollars)

Operating leases

  $40,151  $30,970  $27,428  $23,853  $21,008  $153,403  $296,813  $51,734  $60,808  $44,415  $41,453  $37,760  $187,638  $423,808

Purchase obligations:

                            

Crude oil

   901,995   901,995   901,995   901,995   901,995   1,127,494   5,637,469   1,943,668   1,943,668   1,943,668   1,943,668   1,943,670   485,917   10,204,259

Other purchase obligations

   64,224   20,521   16,520   1,398   962   743   104,368   23,561   18,329   2,197   1,036   744   -   45,867

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Rental expense for all operating leases totaled $64.8 million, $45.2 million $21.0 million and $15.3$21.0 million for the years ended December 31, 2009, 2008 2007 and 2006,2007, respectively. Our operating leases consist primarily of leasesthe following:

a ten-year lease for tugtugs and barges utilized at our St. Eustatius facility for bunker fuel sales, with two five-year renewal options;

a five-year lease for tugs utilized at our Point Tupper facility for bunker fuel sales, with a two-year renewal option;

a five-year lease related to our asphalt and fuels marketing segment for tugs and barges utilized on the east coast;

leases related to our acquisition of the East Coast Asphalt Operationsasphalt and fuels marketing segment for storage capacity at third-party terminals with lease terms generally ranging from two to five years; and

land leases at various terminal facilities. In 2008, we entered into a ten-year lease commitment of approximately $89.0 million for tugs and barges to be utilized at our St. Eustatius facility.

Our crude oil purchase obligations result from a crude supply agreement (CSA) we entered into simultaneously with the acquisition of the East Coast Asphalt Operations. Under the CSA, we committed to purchase an annual average of 75,000 barrels per day of crude oil over a minimum seven-year period from an affiliate of Petróleos de Venezuela S. A. (PDVSA), the national oil company of Venezuela. The value of this commitment fluctuates according to a market-based pricing formula using published market indices, subject to adjustment based on the price of Mexican Maya crude. We estimated the value of the crude oil purchase obligation based on market prices as of December 31, 2008.

In recent months, the Organization of the Petroleum Exporting Countries announced its intention to reduce crude oil production in response to dramatically lower demand for refined products. As a result, we received notice in January 2009 that our scheduled deliveries of Boscan crude oil would be reduced by 600,000 barrels in February and March from

NUSTAR ENERGY L.P. AND SUBSIDIARIES2009.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

the amounts specified in our crude supply agreement with PDVSA. To date, we have replaced the volumes lost from PDVSA with alternative grades of crude oil purchased on the spot market. We have not received notification of any further supply reductions from PDVSA.

We have other purchase obligations mainly related to the purchase of petroleum products for resale to our customers.

16.14. FAIR VALUE MEASUREMENTS

In September 2006, the FASB issued Statement No. 157, “Fair Value Measurements.” Statement No. 157, as amended, defines fair value, establishes a framework for measuring fair value under GAAP, and expands disclosures about fair value measures. The FASB deferred the effective date of Statement No. 157 for one year for all nonfinancial assets and liabilities, except for those items that are recognized or disclosed at fair value in the financial statements on a recurring basis (at least annually). We have applied the recognition and disclosure provisions of Statement No. 157 for financial assets and liabilities and for nonfinancial assets and liabilities that are re-measured at least annually as of January 1, 2008.

We adopted the recognition and disclosure provisions of Statement No. 157 for nonfinancial assets and liabilities that are not recognized or disclosed at fair value on a recurring basis on January 1, 2009. The adoption of these provisions has not materially affected our financial position or results of operations.

Statement No. 157 establishes a fair value hierarchy, which segregatessegregate the inputs used in measuring fair value into three levels: Level 1, defined as observable inputs such as quoted prices in active markets; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs in which little or no market data exists.

We have applied fair value recognition and disclosure provisions for financial assets and liabilities and for nonfinancial assets and liabilities that are re-measured at least annually as of January 1, 2008. As permitted, we applied the provisions for nonfinancial assets and liabilities that are not recognized or disclosed at fair value on a recurring basis as of January 1, 2009, which did not affect our financial position or results of operations.

The following assets and liabilities are measured at fair value on a recurring basis as of December 31, 2008:value:

 

    

Level 1

  

Level 2

  

Level 3

  

Total

 
   (Thousands of Dollars) 

Inventory (FAS 133)

  $(2,441) $-  $-  $(2,441)

Other current assets:

      

Derivatives

   8,502   -   -   8,502 

Product imbalances

   -   11,502   -   11,502 

Other long-term assets, net:

      

Interest rate swaps

   -   15,284   -   15,284 

Accrued liabilities:

      

Firm commitments

   706   -   -   706 

Product imbalances

   -   (2,193)  -   (2,193)
                 

Total

  $    6,767  $    24,593  $-  $    31,360 
                 

Derivatives

A portion of our product inventories and related firm commitments qualify for fair value hedge treatment under Statement No. 133. The fair value of the respective hedged items is determined using quoted public spot market prices. As of December 31, 2007, the portion of our product inventory that qualified for fair value hedge treatment under Statement No. 133 was $1.6 million, and there were no related firm commitments.

Our commodity derivative instruments consist of futures contracts and swaps traded on the NYMEX. Therefore, the fair values of these contracts are based on quoted prices in active markets. We have consistently applied these valuation techniques in all periods presented. As of December 31, 2007, the fair value of our derivative instruments included in “Accrued liabilities” in our consolidated balance sheets was $4.6 million.

Interest Rate Swaps

The fair value of the interest rate swaps was determined using discounted cash flows, which uses observable inputs such as time to maturity and market interest rates. As of December 31, 2007, the aggregate fair value of our interest rate swaps included in “Other long-term assets, net” in our consolidated balance sheets was $2.2 million.

   

December 31, 2009

 
   

Level 1

  

Level 2

  

Level 3

  

Total

 
   (Thousands of Dollars) 

Other current assets:

              

Product imbalances

  $   2,096   $   -   $   -  $   2,096  

Other long-term assets, net:

              

Interest rate swaps

    -     8,623     -    8,623  

Accrued liabilities:

              

Derivatives

    (30,788   -     -    (30,788

Product imbalances

    (676   -     -    (676
                     

Total

  $   (29,368 $   8,623   $   -  $   (20,745
                     
   

December 31, 2008

 
   

Level 1

  

Level 2

  

Level 3

  

Total

 
      (Thousands of Dollars) 

Other current assets:

              

Derivatives

  $   8,502   $   -   $   -  $   8,502  

Product imbalances

    -     11,502     -    11,502  

Other long-term assets, net:

              

Interest rate swaps

    -     15,284     -    15,284  

Accrued liabilities:

              

Product imbalances

    -     (2,193   -    (2,193
                     

Total

  $   8,502   $   24,593   $   -  $   33,095  
                     

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

Derivatives

Our commodity derivative instruments consist of futures contracts and swaps traded on the NYMEX, and the fair values of these contracts are based on their quoted prices. We have consistently applied these valuation techniques in all periods presented.

Interest Rate Swaps

We estimate the fair value of the interest rate swaps using discounted cash flows, which uses observable inputs such as time to maturity and market interest rates.

Product Imbalances

We valueAs of December 31, 2008, we valued assets and liabilities related to product imbalances by petroleum product at adjusted market prices. Effective January 1, 2009, we began using quoted market prices as of the reporting date. date to value our assets and liabilities related to product imbalances.

Fair Value of Financial Instruments

In April 2009, the FASB revised its existing disclosure requirements for the fair value of financial instruments to include the disclosure of the fair value of all financial instruments, whether or not recognized at fair value in the balance sheet, along with the related carrying value and methods and significant assumptions used to estimate the fair value.

We do not record our outstanding debt at fair value in our consolidated balance sheet. The estimated fair value and carrying amount of our fixed-rate debt was as follows:

   

December 31,

   

2009

  

2008

   (Thousands of Dollars)

Fair value

  $1,306,301  $1,157,470

Carrying amount

  $1,248,437  $1,261,234

As of December 31, 2007, we had $13.62009, the fair value and carrying value of our variable rate debt was $551.1 million and $601.3 million, respectively. We estimated the fair values of product imbalance assets and $10.5 millionour debt using a discounted cash flow analysis using current incremental borrowing rates for similar types of product imbalance liabilities in our consolidated balance sheets.borrowing arrangements.

17.15. DERIVATIVES FINANCIAL INSTRUMENTS AND RISK MANAGEMENT ACTIVITIES

We utilize various derivative instruments to: (i) manage our exposure to commodity price risk, (ii) engage in a trading program and (iii) manage our exposure to interest rate risk. Our risk management policies and procedures are designed to monitor interest rates, NYMEX and over-the-counter positions, as well as physical volumes, grades, locations and delivery schedules to help ensure that our hedging activities address our market risks. We have a risk management committee that oversees our trading controls and procedures and certain aspects of commodity and trading risk management. Our risk management committee also approvesreviews all new commodity and trading risk management strategies in accordance with our Risk Management Policy,risk management policy, as approved by our board of directors.

Commodity Price Risk

We are exposedIn March 2008, the FASB amended and expanded the existing disclosure requirements for derivative instruments to commodity price risk with respect to our product inventoriesrequire enhanced disclosures on how and why an entity uses derivative instruments, how derivative instruments and related firm commitments to purchase and/or sell such inventories. We utilize futures contracts and swaps traded on the NYMEX to manage our exposure to changes in the fair value of certain of our product inventories and related firm commitments.

The changes in the fair value of inventories and firm commitments designated as hedged items are accounted for and the resulting ineffectivenesstheir impact on an entity’s financial performance, financial position and cash flows. We adopted these disclosure requirements as of our fair value hedges were as follows:

   

Year Ended December 31,

   

2008

  

2007

   (Thousands of Dollars)

(Decrease) increase in the fair value of inventories and firm commitments

  $(3,344) $1,608

Ineffectiveness gain

  $424  $126

No component of the associated derivative instruments’ gains or losses was excluded from our assessment of hedge ineffectiveness.

The earnings impact of our derivative activity was as follows:

   

Year Ended December 31,

 
   

2008

  

2007

 
   (Thousands of Dollars) 

Commodity price risk hedging gain (loss):

   

Mark-to-market, net

  $9,784  $(3,017)

Settled

   (44,650)  (4,519)
         

Total

  $(34,866) $(7,536)
         

Trading gain (loss):

   

Mark-to-market, net

  $(3) $3 

Settled

   (1,209)  (2,332)
         

Total

  $(1,212) $(2,329)
         

For the year ended December 31, 2008, the commodity price-risk hedging loss includes $60.7 million associated with certain crude oil and intermediate product futures contracts. We entered into these contracts concurrently with our acquisition of the East Coast Asphalt Operations to limit the volatility from price fluctuations on a portion of the inventory we acquired. However, the price of crude oil increased dramatically from the date we entered into the hedges until May 2008, at which time we terminated the contracts prior to their expiration. As of December 31, 2008, we did not have any derivative contracts related to the inventories of the East Coast Asphalt Operations.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

January 1, 2009.

Interest Rate Risk

We are a party to interest rate swap agreements to manage our exposure to changes in interest rates. The interest rate swap agreements have an aggregate notional amount of $167.5 million, of which $60.0 million is tied to the maturity of the 6.875% senior notes and $107.5 million is tied to the maturity of the 6.05% senior notes. Under the terms of the interest rate swap agreements, we will receive a fixed rate (6.875% and 6.05% for the $60.0 million and $107.5 million of interest rate swap agreements, respectively) and will pay a variable rate based on LIBOR plus a percentage that varies with each

agreement. As of December 31, 20082009 and 2007,2008, the weighted-average interest rate forrates that we paid under our interest rate swaps waswere 2.3% and 3.0% and 6.1%, respectively.

Commodity Price Risk

We are exposed to commodity price risk with respect to our product inventories and related firm commitments to purchase and/or sell such inventories. We utilize futures contracts and swaps traded on the NYMEX to manage our exposure to changes in commodity prices, with the objective of stabilizing cash flows.

The estimatedfollowing table presents the volume of our fair value and cash flow derivative positions. The volume of commodity contracts is based on open derivative positions and represents the combined volume of our fixed-rate debtlong and short positions on an absolute basis.

December 31, 2009
(Thousands of barrels)

Commodity contracts – Fair Value Hedges

11,619

Commodity contracts – Cash Flow Hedges

230

The fair values of our derivative instruments included in our consolidated balance sheets were as follows:

   

  Balance Sheet    

  Location

       Asset Derivatives          Liability Derivatives     
    December 31,  December 31, 
    2009  2008  2009  2008 
     (Thousands of Dollars)  

Derivatives Designated as

Hedging Instruments:

             

Interest rate swaps

  Other long-term assets, net  $  8,623  $  15,284  $  -   $  -  

Commodity contracts

  Other current assets   -   7,005   -    (6,911

Commodity contracts

  Accrued liabilities   3,797   -   (14,279  -  
                   

Total

     12,420   22,289   (14,279  (6,911
                   

Derivatives Not Designated

as Hedging Instruments:

             

Commodity contracts

  Other current assets   -   8,408   -    -  

Commodity contracts

  Accrued liabilities   9,766   -   (30,072  -  
                   

Total

     9,766   8,408   (30,072  -  
                   
Total Derivatives    $  22,186  $  30,697  $  (44,351 $  (6,911
                   

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

No component of the associated derivative instruments’ gains or losses was excluded from our assessment of hedge ineffectiveness. The earnings impact of our derivative activity was as follows for the year ended December 31, 2008 and 2007 was $1,157.5 million and $927.2 million, respectively, as compared to the carrying amount of $1,261.2 million and $918.3 million, respectively. These fair values were estimated using discounted cash flow analysis, based on our current incremental borrowing rates for similar types of borrowing arrangements. Interest rates on borrowings under our variable rate debt float with market rates and thus the carrying amount approximates fair value.2009:

Derivatives

Designated as Fair

Value Hedging

Instruments

  

Income Statement
Location

   Amount of Gain
(Loss) Recognized
in Income on
Derivative
(Effective Portion)
  

Amount of Gain
(Loss) Recognized
in Income on
Hedged Item

 

Amount of Gain
(Loss) Recognized

in Income on
Derivative

(Ineffective

Portion)

          (Thousands of Dollars)

Interest rate swaps

  Interest expense, net  $  (6,661   $  6,661  $  - 

Commodity contracts

  Cost of product sales    (22,939     35,512    12,573 
                    

Total

    $  (29,600   $  42,173  $  12,573 
                    

Derivatives

Designated as Cash

Flow Hedging

Instruments

Amount of Gain

(Loss) Recognized

in OCI on

Derivative

(Effective Portion)

Income Statement
Location (a)
Amount of Gain
(Loss) Reclassified
from
Accumulated OCI
into Income
(Effective Portion)
Amount of Gain
(Loss) Recognized
in Income on
Derivative
(Ineffective
Portion)
(Thousands of Dollars)(Thousands of Dollars)

Commodity contracts

$ (240)Cost of product sales$        -$        -

(a)Amounts are included in specified location for both the gain (loss) reclassified from accumulated OCI into income (effective portion) and the gain (loss) recognized in income on derivative (ineffective portion).

Derivatives Not Designated

as Hedging Instruments

Income Statement
Location

Amount of Gain (Loss)

Recognized in Income

(Thousands of Dollars)

Commodity contracts

Cost of product sales$(13,594

Commodity contracts

Operating expenses(3,589

Total

$(17,183

Concentration of Credit Risk

We are exposed to credit risk on our hedging instruments in the event of nonperformance by counterparties. However, because our hedging activities are transacted only with highly rated institutions, we do not anticipate nonperformance by any of these counterparties.

For the year ended December 31, 2008, no single customer accounted for more than 10% of our consolidated operating revenues. For the years ended December 31, 2007 and 2006 we derived approximately 18% and 23%, respectively, of our revenues from Valero Energy and its subsidiaries, our largest customer, and no other single customer accounted for more than 10% of our consolidated operating revenues.

18.16. RELATED PARTY TRANSACTIONS

Our operations are managed by the general partner of our general partner, NuStar GP, LLC. The employees of NuStar GP, LLC perform services for our U.S. operations. Certain of our wholly owned subsidiaries employ persons who perform services for our international operations. We reimburse NuStar GP, LLC for all costs related to its employees, other than costs associated with NuStar GP Holdings under the services agreement described below. We had a payable of $3.4$10.6 million and a receivable of $0.8$3.4 million as of December 31, 20082009 and 2007,2008, respectively, with both amounts representing payroll, and

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

employee-related benefit plan costs, net of payments made by us.expenses and unit-based compensation. We also had a long-term payable as of December 31, 2009 and 2008 and 2007 of $6.6$7.7 million and $5.7$6.6 million, respectively, to NuStar GP, LLC related to amounts payable for retiree medical benefits and other post-employment benefits.

Prior to December 22, 2006, Valero Energy controlled our general partner. We have transactions with Valero Energy for pipeline tariff, terminalling fee and crude oil storage tank fee revenues, certain employee costs, insurance costs, administrative costs and lease expense, which were reported as related party transactions in the consolidated statements of income. Due to Valero Energy’s sale of its interest in NuStar GP Holdings on December 22, 2006, we ceased reporting transactions with Valero Energy as related party transactions subsequent to that date.

The following table summarizes information pertaining to related party transactions with NuStar GP, LLC for the years ended December 31, 2008 and 2007 and with Valero Energy for the year ended December 31, 2006:LLC:

 

  

Year Ended December 31,

    Year Ended December 31,
  

2008

  

2007

  

2006

    2009    2008    2007
  (Thousands of Dollars)    (Thousands of Dollars)

Revenues

  $-  $-  $    260,980

Operating expenses

       115,291       93,211   94,587    $  124,827    $  115,291    $  93,211

General and administrative expenses

   44,988   37,702   32,183    58,878    44,988    37,702

Agreements with NuStar GP Holdings

GP Services Agreement. InOn April 24, 2008, the boards of directors of NuStar GP, LLC and NuStar GP Holdings approved (i) the termination of the administration agreement, dated July 16, 2006, between NuStar GP Holdings and NuStar GP,

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

LLC (the Administration Agreement) and (ii) the adoption of a services agreement between NuStar GP, LLC and NuStar Energy (the GP Services Agreement). All employees providing services to both NuStar GP Holdings and NuStar Energy are employed by NuStar GP, LLC.

Under the Administration Agreement, NuStar GP Holdings paid annual charges of $500,000, subject to certain adjustments, to NuStar GP, LLC in return for NuStar GP, LLC’s provision of all executive management, accounting, legal, cash management, corporate finance and other administrative services to NuStar GP Holdings. NuStar GP Holdings also reimbursed NuStar GP, LLC for all direct public company costs and any other direct costs, such as outside legal and accounting fees, that NuStar GP, LLC incurred while providing services to NuStar GP Holdings.

In connection with the terminationEffective as of the Administration Agreement,January 1, 2008, NuStar Energy and NuStar GP, LLC entered into the GP Services Agreement, effective as of January 1, 2008.Agreement. The GP Services Agreement provides that NuStar GP, LLC will furnish all administrative and certain operating services necessary for theto conduct of the business of NuStar Energy,Energy. All employees providing services to both NuStar GP Holdings and NuStar Energy will reimburseare employed by NuStar GP, LLC; therefore, NuStar Energy reimburses NuStar GP, LLC for all employee costs, other than the expenses allocated to NuStar GP Holdings (the Holdco Administrative Services Expense).

For 2008,the 2009 fiscal year and each fiscal year thereafter, the Holdco Administrative Services Expense totaled $750,000,totals $1.1 million (as adjusted), plus 1.0% of NuStar GP, LLC’s domestic bonus and unit compensation expense, for the 2008 fiscal year and subject to certain other adjustments. For 2008, the Holdco Administrative Services Expense totaled $0.8 million, plus 1.0% of NuStar GP, LLC’s domestic bonus and unit compensation expense. The GP Services Agreement will terminate on December 31, 2012, with automatic two-year renewals unless terminated by either party upon six months’ prior written notice. The aggregate amounts allocated to NuStar GP Holdings related to the Administration Agreement and the GP Services Agreement were $1.4 million, $0.9 million $0.5 million and $0.3$0.5 million for the years ended December 31, 2009, 2008 2007 and 2006,2007, respectively.

Non-Compete Agreement. On July 19, 2006, we entered into a non-compete agreement with NuStar GP Holdings, Riverwalk Logistics, L.P., and NuStar GP, LLC (the Non-Compete Agreement). The Non-Compete Agreement became effective on December 22, 2006 when NuStar GP Holdings ceased to be subject to the Amended and Restated Omnibus Agreement, dated March 31, 2006. Under the Non-Compete Agreement, we will have a right of first refusal with respect to the potential acquisition of assets that relate to the transportation, storage or terminalling of crude oil, feedstocks or refined petroleum products (including petrochemicals) in the United States and internationally. NuStar GP Holdings will have a right of first refusal with respect to the potential acquisition of general partner and other equity interests in publicly traded partnerships under common ownership with the general partner interest. With respect to any other business opportunities, neither the Partnership nor NuStar GP Holdings are prohibited from engaging in any business, even if the Partnership and NuStar GP Holdings would have a conflict of interest with respect to such other business opportunity.

Agreements with Valero Energy

We are a party to a number of operating agreements with Valero Energy, which was a related party during 2006, that govern the required services provided to and received from Valero Energy. Most of the operating agreements include adjustment provisions, which allow us to increase the handling, storage and throughput fees we charge to Valero Energy based on a consumer price index. In addition, we review our pipeline tariffs, which are adjusted annually based on an inflation index and may also be adjusted to take into consideration additional costs incurred to provide the transportation services. The following summarizes the significant terms of the individual agreements.

Services Agreement.     Prior to our separation from Valero Energy, the employees of NuStar GP, LLC were provided to us under the terms of various services agreements between us and Valero Energy. The terms of these services agreements generally provided that the costs of employees who performed services directly on our behalf, including salaries, wages and employee benefits, were charged directly to us. In addition, Valero Energy charged us a net administrative services fee, which was $1.8 million for the year ended December 31, 2006.

Although Valero Energy no longer provided employees to work directly on our behalf during 2007, they continued to provide certain services to us under the terms of a services agreement dated December 22, 2006 (the 2007 Services Agreement). Under the 2007 Services Agreement, we paid Valero Energy approximately $1.1 million for the year ended December 31, 2007 for certain administrative services and telecommunication services. On April 16, 2007, Valero Energy exercised its option to terminate the 2007 Services Agreement. In accordance with the terms of the 2007 Services Agreement, Valero Energy paid us a termination fee of $13.0 million in May 2007 and continued providing certain services over a period of time sufficient to allow us to assume those functions by the end of 2007.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Omnibus Agreement.     On March 31, 2006, we entered into an amended and restated omnibus agreement (the 2006 Omnibus Agreement) with Valero Energy, NuStar GP, LLC, Riverwalk Logistics, L.P., and NuStar Logistics. The 2006 Omnibus Agreement superseded the Omnibus Agreement among the parties dated effective April 16, 2001. The 2006 Omnibus Agreement governed potential competition between Valero Energy and us. With the closing of NuStar GP Holding’s secondary public offering on December 22, 2006, Valero Energy ceased to own 20% or more of us, which allows Valero Energy to compete with us. Also under the 2006 Omnibus Agreement, Valero Energy agreed to indemnify us for environmental liabilities related to the assets transferred to us in connection with our initial public offering, provided that such liabilities arose prior to and are discovered within ten years after that date (excluding liabilities resulting from a change in law after April 16, 2001).

Pipelines and Terminals Usage Agreement - McKee, Three Rivers and Ardmore.    Under the terms of the Pipelines and Terminals Usage Agreement dated April 16, 2001, we provided transportation services that support Valero Energy’s refining and marketing operations relating to the McKee, Three Rivers and Ardmore refineries. Pursuant to the agreement, Valero Energy had agreed through April 2008:

to transport in our crude oil pipelines at least 75% of the aggregate volumes of crude oil shipped to the McKee, Three Rivers and Ardmore refineries;

to transport in our refined product pipelines at least 75% of the aggregate volumes of refined products shipped from the McKee, Three Rivers and Ardmore refineries; and

to use our refined product terminals for terminalling services for at least 50% of all refined products shipped from the McKee, Three Rivers and Ardmore refineries.

In the event Valero Energy did not transport in our pipelines or use our terminals to handle the minimum volume requirements and if its obligation has not been suspended under the terms of the agreement, Valero Energy would have been required to make a cash payment determined by multiplying the shortfall in volume by the applicable weighted average pipeline tariff or terminal fee. For the period from January 1, 2008 through April 15, 2008 and the years ended December 31, 2007 and 2006, Valero Energy exceeded its obligations under the Pipelines and Terminals Usage Agreement. Additionally, Valero Energy had agreed not to challenge, or cause others to challenge, our interstate or intrastate tariffs for the transportation of crude oil and refined products. The Pipelines and Terminals Usage Agreement expired on April 16, 2008.

Crude Oil Storage Tank Agreements.    In conjunction with the acquisition of the Crude Oil Storage Tanks in March 2003, we entered into the following agreements with Valero Energy:

Handling and Throughput Agreement, dated March 2003, pursuant to which Valero Energy agreed to pay us a fee for 100% of crude oil and certain other feedstocks delivered to the Corpus Christi West refinery, the Texas City refinery and the Benicia refinery and to use our logistic assets for handling all deliveries to these refineries. The throughput fees are adjustable annually, generally based on 75% of the regional consumer price index applicable to the location of each refinery. The initial term of the handling and throughput agreement is ten years, which may be extended by Valero Energy for up to an additional five years.

Services and Secondment Agreements, dated March 2003, pursuant to which Valero Energy agreed to provide personnel to us who perform operating and routine maintenance services related to the crude oil storage tank operations. The annual reimbursement for those services is an aggregate $3.5 million. The initial term of the services and secondment agreements is ten years, which we may extend for an additional five years. In addition to the fees we have agreed to pay Valero Energy under the services and secondment agreements, we are responsible for operating expenses and specified capital expenditures related to the tank assets that are not addressed in the services and secondment agreements. These operating expenses and capital expenditures include tank safety inspections, maintenance and repairs, certain environmental expenses, insurance premiums and ad valorem taxes.

Lease and Access Agreements, dated March 2003, pursuant to which Valero Energy leases to us the land on which the crude oil storage tanks are located for an aggregate amount of $0.7 million per year. The initial term of each lease is 25 years, subject to automatic renewal for successive one-year periods thereafter. We may terminate any of these leases upon 30 days notice after the initial term or at the end of a renewal period. In addition, we may terminate any of these leases upon 180 days notice prior to the expiration of the current term if we cease to operate the crude oil storage tanks or cease business operations.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

South Texas Pipelines and Terminals Agreements.    In conjunction with the acquisition of the South Texas Pipelines and Terminals in March 2003, we entered into the following agreements with Valero Energy:

Terminalling Agreement,dated March 2003, pursuant to which Valero Energy agreed, during the initial period of five years, to pay a terminalling fee for each barrel of refined product stored or handled by or on behalf of Valero Energy at the terminals, including an additive fee for gasoline additive blended at the terminals. At the Houston Hobby Airport terminal, Valero Energy agreed to pay a filtering fee for each barrel of jet fuel stored or handled at the terminal.

Throughput Commitment Agreement,dated March 2003, pursuant to which Valero Energy agreed, for an initial period of seven years:

-

to transport in the Houston and Valley pipeline systems an aggregate of 40% of the Corpus Christi refineries’ gasoline and distillate production but only if the combined throughput in these pipelines is less than 110,000 barrels per day;

-

to transport in the Pettus to San Antonio refined product pipeline 25% of the Three Rivers refinery gasoline and distillate production and in the Pettus to Corpus Christi refined product pipeline 90% of the Three Rivers refinery raffinate production;

-

to use the Houston asphalt terminal for an aggregate of 7% of the asphalt production of the Corpus Christi refineries;

-

to use the Edinburg refined product terminal for an aggregate of 7% of the gasoline and distillate production of the Corpus Christi refineries, but only if the throughput at this terminal is less than 20,000 barrels per day; and

-

to use the San Antonio East terminal for 75% of the throughput in the Pettus to San Antonio refined product pipeline.

In the event Valero Energy does not transport in our pipelines or use our terminals to handle the minimum volume requirements and if its obligation has not been suspended under the terms of the agreement, Valero Energy will be required to make a cash payment determined by multiplying the shortfall in volume by the applicable weighted average pipeline tariff or terminal fee. Valero Energy’s obligation to transport 90% of the Three Rivers refinery raffinate production in the Pettus to Corpus Christi refined product pipeline was suspended in the fourth quarter of 2005 due to the temporary idling of the pipeline in the fourth quarter of 2005.

St. James Terminalling Agreement.     On December 1, 2006, we executed a terminal services agreement with Valero Energy for the St. James, Louisiana crude oil facility (the St. James Terminal Agreement). Pursuant to the St. James Terminal Agreement, we will provide crude oil storage and blending services to Valero Energy for a minimum throughput fee of $1.175 million per month, plus $0.08 per barrel throughput in excess of 4 million barrels per month and $0.03 per barrel blended. The St. James Terminal Agreement has an initial term of five years, with an option to extend for an additional five years, provided that Valero Energy provides notice of its intent to extend the term at least one year prior to the expiration of the initial term.

19.17. EMPLOYEE BENEFIT PLANS AND LONG-TERM INCENTIVE PLANS

Employee Benefit Plans

We rely on employees of NuStar GP, LLC to provide the necessary services to conduct our U.S. operations. Prior to July 1, 2006, the employees of NuStar GP, LLC were included in thesponsors various employee benefit plans of Valero Energy, which included a defined benefit pension plan, a retiree welfare benefit plan, health and welfare benefits, a defined contribution retirement plan, equity incentive plans and nonqualified deferred compensation plans. On July 1, 2006, employees of NuStar GP, LLC began participating in newly enacted, comparable plans sponsored by NuStar GP, LLC.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

The NuStar Pension Plan (the Pension Plan) is a qualified non-contributory defined benefit pension plan that became effective July 6,1, 2006. The Pension Plan covers substantially all of NuStar GP, LLC’s employees and generally provides eligible employees with retirement income calculated under a defined benefit formula based on years of service and compensation during thetheir period of service. Employees may become eligible to receivefully vested in their Pension Plan benefits afterupon attaining five years of service, which includes service recognized by Valero Energy for vesting purposes under the Valero Energy pension plan. All benefit obligations associated with service for certain employees who were participants in the Valero Energy pension plan through June 30, 2006, including the effect of future salary increases, are the responsibility of Valero Energy. All benefit obligations related to service by NuStar GP, LLC employees on or after July 1, 2006 will be covered by the Pension Plan. Effective January 1, 2008, that plan was amended to comply with changes to Internal Revenue Code Section 409A (Section 409A) and change the name of the

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

plan. The Pension Plan was further amended effective January 1, 2009 to require employees to complete one “year of service,” as defined in the Pension Plan, in order to participate in the Pension Plan.service.

NuStar GP, LLC also hasmaintains an excess pension plan (the Excess Pension Plan) and a supplemental executive retirement plan (the SERP). The Excess Pension Plan and the SERP are nonqualified deferred compensation plans that provide benefits to a select group of management or other highly compensated employees of NuStar GP, LLC. TheBenefits under the Excess Pension Plan and the SERP were each amended effective January 1, 2008 to comply with changes to Section 409A.are generally payable in a single lump sum payment upon the employee’s separation from service.

The NuStar Thrift Plan (the Thrift Plan) is a qualified employee profit-sharing plan whichthat became effective June 26, 2006. Participation in the Thrift Plan is voluntary and is open to substantially all of NuStar GP, LLC employees upon their date of hire, except for part-time employees (as defined in the Thrift Plan), who become eligible to participate upon datecompleting one year of hire.service (as defined in the Thrift Plan). Thrift Plan participants can make basic contributionscontribute from 1% up to 30% of their total annual compensation. The maximum match bycompensation to the Thrift Plan in the form of pre-tax and/or after tax employee contributions. NuStar GP, LLC was 75% of each participant's basicmakes matching contributions up to 8% based on the participant's total annual compensation. Effective January 1, 2008, the Thrift Plan was amended to comply with changes to Section 409A and change the maximum match by NuStar GP, LLCin an amount equal to 100% of each participant’s total contributionemployee contributions up to a maximum of 6% based onof the participant’s total annual compensation. The Thrift Plan was further amended effective January 1, 2009 to require temporary employees to complete one year of service in order to participate in the Thrift Plan (“temporary employees” and “year of service,” each as defined in the Thrift Plan).

NuStar GP, LLC also hasmaintains an excess thrift plan (the Excess Thrift Plan) whichthat became effective July 1, 2006 and provides benefits to a select group of management or other highly compensated employees.2006. The Excess Thrift Plan is a nonqualified deferred compensation plan that provides benefits to those employees of NuStar GP, LLC whose compensation and/or annual additionscontributions under the Thrift Plan are subject to the limitations applicable to qualified retirement plans under the Internal Revenue Code. TheCode of 1986, as amended. Benefits under the Excess Thrift Plan was amended effective January 1, 2008 to comply with changes to Section 409A.are generally payable in a single lump sum payment upon the employee’s separation from service.

NuStar GP, LLC also provides a post-retirement medical benefits plan for retired employees, referred to as other post-retirement benefits.

None of the Excess Thrift Plan, the Excess Pension Plan or the SERP is intended to constitute either a qualified plan under the provisions of Section 401 of the Code or a funded plan subject to ERISA. All costs incurred by NuStar GP, LLC related to these employee benefit plans were and will continue to be reimbursed by us at cost.

Long-Term Incentive Plans

NuStar GP, LLC also sponsors the following:

 

The Second Amended and Restated 2000 Long-Term Incentive Plan (the 2000 LTIP), under which NuStar GP, LLC may award up to 1,500,000 NuStar Energy common units. Awards under the 2000 LTIP can include unit options, restricted units, performance awards, distribution equivalent rights (DERs)(DER) and contractual rights to receive common units. As of December 31, 2008,2009, a total of 471,117294,394 common units remained available to be awarded under the 2000 LTIP.

 

The 2003 Employee Unit Incentive Plan (the UIP) under which NuStar GP, LLC may award up to 500,000 NuStar Energy common units to employees of NuStar GP, LLC or its affiliates, excluding officers and directors of NuStar GP, LLC and its affiliates. Awards under the UIP can include unit options, restricted units and DERs.DER. As of December 31, 2008,2009, a total of 259,719254,812 common units remained available to be awarded under the UIP.

 

The 2002 Unit Option Plan (the UOP) under which NuStar GP, LLC may award up to 200,000 NuStar Energy unit options to officers and directors of NuStar GP, LLC or its affiliates, of which substantially all of the unit options have been awarded as of December 31, 2008.2009.

 

The 2006 Long-Term Incentive Plan (the 2006 LTIP) under which NuStar GP Holdings may award up to 2,000,000 units to employees, consultants and directors of NuStar GP Holdings and its affiliates, including us. Awards under the 2006 LTIP can include unit options, performance units, restricted units, phantom units, unit grants and unit appreciation rights of NuStar GP Holdings, LLC. As of December 31, 2008,2009, a total of 1,627,0291,595,689 NuStar GP Holdings units remained available to be awarded under the 2006 LTIP.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

Our share of compensation expense related to the various long-term incentive plans described above totaled $5.3 million, $3.8 million and $2.4 million, respectively, for the years ended December 31, 2008, 2007 and 2006. We record such amounts in “General and administrative expenses” in the consolidated statements of income for those years.

The number of awards granted under the above notedabove-described plans were as follows:

 

  

Year Ended December 31,

 Year Ended December 31,
  

2008

  

2007

  

2006

 2009  2008  2007
  

Granted

  

Vesting

  

Granted

  

Vesting

  

Granted

  

Vesting

 Granted  Vesting  Granted  Vesting  Granted  Vesting

2000 LTIP:

                       

Performance awards

  14,470  (a)  10,840  (a)  8,940  (a) 23,233  (a)  14,470  (a)  10,840  (a)

Unit options

  10,670  1/5 per year  204,675  1/5 per year  203,975  1/5 per year -  -  10,670  1/5 per year  204,675  1/5 per year

Restricted units

  236,868  1/5 per year  117,575  1/5 per year  51,140  1/5 per year 194,973  1/5 per year  236,868  1/5 per year  117,575  1/5 per year

Restricted units (grants to non-employee directors of NuStar GP, LLC) (b)

  5,625  1/3 per year  3,510  1/3 per year  2,307  1/3 per year 5,076  1/3 per year  5,625  1/3 per year  3,510  1/3 per year

UIP:

                       

Unit options

  795  1/5 per year  -  -  15,200  1/5 per year -  -  795  1/5 per year  -  -

Restricted units

  13,795  1/5 per year  12,730  1/5 per year  9,740  1/5 per year 10,692  1/5 per year  16,321  1/5 per year  12,730  1/5 per year

2006 LTIP:

                       

Restricted units

 24,290  1/5 per year  30,300  1/5 per year  -  -

Unit options

  -  -  324,100  (c)  -  - -  -  -  -  324,100  (c)

Restricted units

  30,300  1/5 per year  -  -  -  -

Restricted units (grants to non-employee directors of NuStar GP Holdings) (b)

  10,308  1/3 per year  5,489  1/3 per year  2,886  1/3 per year 8,627  1/3 per year  10,308  1/3 per year  5,489  1/3 per year

 

 (a)

Performance awards vest 1/3 per year if certain performance measures are met.

 (b)

We do not reimburse NuStar GP, LLC for compensation expense relating to these plans.

awards.
 (c)

Unit options granted under the 2006 LTIP vest in annual one-third increments beginning on the third anniversary of the grant date.

Our share of compensation expense related to the various long-term incentive plans and benefit plans described above is as follows:

   Year Ended December 31,
   2009  2008  2007
   (Thousands of Dollars)

Long-term incentive plans

  $  15,060  $  5,254  $  3,833

Benefit plans

   9,359   8,196   8,704

20.18. OTHER INCOME

Other income consisted of the following:

 

  

Year Ended December 31,

 Year Ended December 31, 
  

2008

  

2007

 

2006

 2009 2008  2007 
  (Thousands of Dollars) (Thousands of Dollars) 

Sale of interest in Skelly-Belvieu (see Note 10)

  $18,867  $-  $-

Sale or disposal of fixed assets

   7,589   7,869   474

Business interruption insurance

   3,504   12,492   -

2007 Services Agreement termination fee (see Note 18)

   -   13,000   -

Gain from sale or disposition of assets

 $ 21,320   $  26,456  $  7,869  

Gain from insurance proceeds

  9,382    3,504   12,492  

2007 Services Agreement termination fee

  -    -   13,000  

Legal settlements

   -   5,758   -  -    -   5,758  

Foreign exchange gains (losses)

   5,888   (6,261)  1,011  (5,118  5,888   (6,261

Other

   1,891   5,972   1,767  6,275    1,891   5,972  
                     

Other income, net

  $37,739  $38,830  $3,252 $ 31,859   $  37,739  $  38,830  
                     

The

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

For the year ended December 31, 2009, the sale or disposal of fixed assets includes a gain of $21.4 million related to the June 15, 2009 sale of the Ardmore-Wynnewood pipeline in Oklahoma and the Trans-Texas pipeline. For the year ended December 31, 2008, the sale or disposal of fixed assets includes a gain of $18.9 million related to the sale of interest in Skelly-Belvieu.

For the year ended December 31, 2009, the gain from insurance proceeds results from insurance claims related to damage caused by Hurricane Ike primarily at our Texas City terminal in the third quarter of 2008. For the years ended December 31, 2008 and 2007, the gain from insurance proceeds relates to business interruption insurance amount consists of insurance proceeds related toassociated with lost earnings in 2007 at our pipelines and terminals that serve Valero Energy’s McKee refinery, which experienced a fire in February 2007.

NUSTAR ENERGY L.P. AND SUBSIDIARIESValero Energy provided certain services to us under the terms of a services agreement dated December 22, 2006 (the 2007 Services Agreement). On April 16, 2007, Valero Energy exercised its option to terminate the 2007 Services Agreement. In accordance with the terms of the 2007 Services Agreement, Valero Energy paid us a termination fee of $13.0 million at that time.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

21.19. PARTNERS’ EQUITY ALLOCATIONS OF NET INCOME AND CASH DISTRIBUTIONS

Partners’ EquityIssuance of Common Units

In November 2009, we issued 5,750,000 common units representing limited partner interests at a price of $52.45 per unit. We received net proceeds of $288.8 million and a contribution of $6.2 million from our general partner to maintain its 2% general partner interest. The net proceeds were used mainly to reduce the outstanding principal balance under our 2007 Revolving Credit Agreement.

In April 2008, we issued 5,050,800 common units representing limited partner interests at a price of $48.75 per unit. We received net proceeds of $236.2 million and a contribution of $5.0 million from our general partner to maintain its 2% general partner interest. The proceeds were used to repay the $124.0 million balance under our then-activea term loan agreement and a portion of the outstanding principal balance under our 2007 Revolving Credit Agreement.

OnIn November 19, 2007, we issued 2,600,000 common units representing limited partner interests at a price of $57.20 per unit. We received net proceeds of $143.1 million and a contribution of $3.0 million from our general partner to maintain its 2% general partner interest. The proceeds were used to repay a portion of the outstanding principal balance under our then-active $600 million revolving credit agreement.

Subordinated UnitsComprehensive Income (Loss)

Effective April 1, 2006, we satisfied allChanges in the conditionsamounts included in our partnership agreement for“Accumulated other comprehensive income (loss)” were as follows:

   Foreign
Currency
Translation
  Cash Flow
Hedges
  Accumulated
Other
Comprehensive
Income (Loss)
 

Balance as of January 1, 2008

  $  26,887   $   -   $  26,887  

Foreign currency translation

    (41,153   -    (41,153
               

Balance as of December 31, 2008

  $  (14,266 $   -   $  (14,266
               

Foreign currency translation

    22,316     -    22,316  

Unrealized loss on cash flow hedges

    -     (240  (240
               

Balance as of December 31, 2009

  $  8,050   $   (240 $  7,810  
               

There was no tax effect from foreign currency translation or the subordination period to end. Accordingly, all 9,599,322 subordinated units converted into common unitsunrealized loss on a one-for-one basis on May 8, 2006, the first business day after the record date for the distributioncertain derivative instruments as these transactions related to the first quarter earnings of 2006. Riverwalk Holdings, LLC held the 9,599,322 subordinated units at the time of conversion.non-taxable entities.

Allocations of Net Income

Our partnership agreement, as amended, sets forth the calculation to be used to determine the amount and priority of cash distributions that the common unitholders, subordinatedour unitholders and general partner will receive. The partnership agreement also contains provisions for the allocation of net income and loss to theour unitholders and the general partner. For purposes of maintaining partner

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

capital accounts, the partnership agreement specifies that items of income and loss shall be allocated among the partners in accordance with their respective percentage interests. Normal allocations according to percentage interests are done after giving effect, if any, to priority income allocations in an amount equal to incentive cash distributions allocated 100% to the general partner.

During the year ended December 31, 2006, our general partner reimbursed us for certain charges we incurred related to services historically provided under our services agreement with Valero Energy. United States generally accepted accounting principles required us to record the charges as expenses and record the reimbursement as a capital contribution.

The following table details the calculation of net income applicable to the general partner:

 

 Year Ended December 31,
  

Year Ended December 31,

  2009  2008  2007
  

2008

  

2007

  

2006

  (Thousands of Dollars)
  (Thousands of Dollars) 

Net income applicable to general partner and limited partners’ interest

  $    254,018  $    150,298  $    149,530  $ 224,875  $  254,018  $  150,298

Charges reimbursed by general partner

   -   -   575 
          

Net income before charges reimbursed by general partner

   254,018   150,298   150,105 

Less general partner incentive distribution (a)

   24,764   18,426   14,778   28,712   24,764   18,426
                     

Net income before charges reimbursed by general

partner and after general partner incentive distribution

   229,254   131,872   135,327 

Net income after general partner incentive distribution

  196,163   229,254   131,872

General partner interest

   2%   2%   2%   2%   2%   2%
                     

General partner allocation of net income before charges reimbursed by general partner and after general partner incentive distribution

   4,586   2,637   2,707 

Charges reimbursed by general partner

   -   -   (575)

General partner allocation of net income after general partner incentive distribution

  3,924   4,586   2,637

General partner incentive distribution

   24,764   18,426   14,778   28,712   24,764   18,426
                     

Net income applicable to general partner

  $29,350  $21,063  $16,910  $ 32,636  $  29,350  $  21,063
                     

 

 (a)

For the first quarter of 2008, our net income allocation to general and limited partners reflected a total cash distribution based on the partnership interests outstanding as of March 31, 2008. We issued approximately 5.1

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

million common units in April 2008. Actual distribution payments are made within 45 days after the end of each quarter as of a record date that is set after the end of each quarter. As such,Therefore, the general partner’s portion of the actual distribution made with respect to the first quarter 2008, including the incentiveIDR, which is shown in the distribution rights, was greater thantable below, exceeded the net income allocation to the general partner.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Net Income per Unit

In 2008, the FASB provided additional guidance regarding the application of the two-class method to calculate earnings per unit for master limited partnerships, which was effective January 1, 2009. The following table details the calculation of earnings per unit:

  

Year Ended December 31,

 
        2009  2008  2007 
    (Thousands of Dollars, Except Per Unit Data) 

Net income

 

$

 224,875   $  254,018  $  150,298  

Less general partner distribution (including IDR) (a)

  34,142    29,711   22,518  

Less limited partner distribution

  237,308    217,494   182,076  
            

Distributions (greater than) less than earnings

 

$

 (46,575 $  6,813  $  (54,296
            

General partner earnings:

       

Distributions

 

$

 34,142   $  29,711  $  22,518  

Allocation of distributions (greater than) less than earnings (2%)

  (932  136   (1,086
            

Total

 

$

 33,210   $  29,847  $  21,432  
            

Limited partner earnings:

       

Distributions

 

$

 237,308   $  217,494  $  182,076  

Allocation of distributions (greater than) less than earnings (98%)

  (45,643  6,677   (53,210
            

Total

 

$

 191,665   $  224,171  $  128,866  
            

Weighted average limited partner units outstanding

  55,232,467    53,182,741   47,158,790  

Net income per unit applicable to limited partners:

       

Distributions

 

$

 4.30   $  4.09  $  3.86  

Distributions (greater than) less than earnings

  (0.83  0.13   (1.13
            

Total

 

$

 3.47   $  4.22  $  2.73  
            

(a)For the first quarter of 2008, the general partner distribution used in our calculation of earnings per unit was based on the partnership interests outstanding as of March 31, 2008. We issued approximately 5.1 million common units in April 2008. Actual distribution payments are made within 45 days after the end of each quarter as of a record date that is set after the end of each quarter. Therefore, the general partner’s portion of the actual distribution made with respect to the first quarter 2008, including the IDR, which is shown in the distribution table below, exceeded the general partner distribution used in the calculation of earnings per unit.

Cash Distributions

We make quarterly distributions of 100% of our available cash, generally defined as cash receipts less cash disbursements and cash reserves established by the general partner, in its sole discretion. These quarterly distributions are declared and paid within 45 days subsequent to each quarter-end. The limited partner unitholders are entitled to receive a minimum quarterly distribution of $0.60 per unit each quarter ($2.40 annualized). Our cash is first distributed 98% to the limited partners and 2% to the general partner until there has beenthe amount distributed to theour unitholders an amountis equal to the minimum quarterly distribution and arrearages in the payment of the minimum quarterly distribution for any prior quarter. Thirdly, cashCash in excess of the minimum quarterly distributions is distributed to theour unitholders and theour general partner based on the percentages shown below.

The

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Our general partner is entitled to incentive distributions if the amount we distribute with respect to any quarter exceeds specified target levels shown below:

 

   Percentage of Distribution
Quarterly Distribution Amount per Unit  Unitholders  General Partner

Up to $0.60

  98%  2%

Above $0.60 up to $0.66

  90%  10%

Above $0.66

  75%  25%

The following table reflects the allocation of total cash distributions to theour general and limited partners applicable to the period in which the distributions are earned:

 

 Year Ended December 31, 
  

Year Ended December 31,

 2009 2008 2007 
  

2008

  

2007

  

2006

 (Thousands of Dollars, Except Per Unit Data) 
  (Thousands of Dollars, Except Per Unit Data)

General partner interest

  $5,058  $4,092  $3,742 

$

 5,430   $ 5,058   $ 4,092  

General partner incentive distribution

   25,294   18,426   14,778  28,712    25,294    18,426  
                     

Total general partner distribution

   30,352   22,518   18,520  34,142    30,352    22,518  

Limited partners’ distribution

   222,470   182,076   168,515  237,308    222,470    182,076  
                     

Total cash distributions

  $252,822  $204,594  $187,035 

$

 271,450   $ 252,822   $ 204,594  
                     

Cash distributions per unit applicable to limited partners

  $4.085  $3.835  $3.600 

$

 4.245   $ 4.085   $ 3.835  
                     

In January 2009,2010, we declared a quarterly cash distribution of $1.0575$1.065 that was paid on February 12, 20092010 to unitholders of record on February 5, 2009.2010. This distribution related to the fourth quarter of 20082009 and totaled $65.8$73.4 million, of which $8.2$9.3 million represented theour general partner’s share of such distribution. TheOur general partner’s distribution included a $6.9$7.8 million incentive distribution.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

22.20. CONSOLIDATED STATEMENTS OF CASH FLOWS

Changes in current assets and current liabilities were as follows:

 

  

Year Ended December 31,

  Year Ended December 31, 
  

2008

 

2007

 

2006

  2009   2008   2007 
  (Thousands of Dollars)  (Thousands of Dollars) 

Decrease (increase) in current assets:

          

Accounts receivable

  $(52,372) $  (22,079) $27,307  

$

 (31,505 $  (52,372 $  (22,079

Receivable from related party

   786   (786)  1,168   -    786    (786

Inventories

   193,992   (71,457)  257   (156,234  193,992    (71,457

Other current assets

   6,920   (8,603)  6,181   (39,400  6,920    (8,603

Increase (decrease) in current liabilities:

          

Payable to related party

   3,760   (2,315)  (9,493)  7,051    3,760    (2,315

Accounts payable

   (16,419)  72,918   (7,106)  59,284    (16,419  72,918  

Accrued interest payable

   4,781   182   1,135   (969  4,781    182  

Accrued liabilities

   (13,237)  9,546   (8,300)  17,492    (13,237  9,546  

Taxes other than income taxes

   4,730   2   1,345 

Income taxes payable

   76   1,266   (1,799)

Taxes other than income tax

  209    4,730    2  

Income tax payable

  (8,208  76    1,266  
                      

Changes in current assets and current liabilities

  $  133,017  $(21,326) $  10,695  

$

 (152,280 $  133,017   $  (21,326
                      

The above changes in current assets and current liabilities differ from changes between amounts reflected in the applicable consolidated balance sheets for the following reasons:

the amounts shown above exclude the current assets and current liabilities acquired in connection with the East Coast Asphalt Operations acquisition; and

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

certain differences between consolidated balance sheet changes and amounts reflected above result from translating foreign currency denominated amounts at different exchange rates.

Non-cash financing activities for the year ended December 31, 2009 included a decrease in the fair value of our interest rate swaps.

Non-cash investing and financing activities for the year ended December 31, 2008 included:

adjustment to property, plant and equipment and other long-term assets relating to a non-amortizing asset on our ammonia pipeline;

increase in the fair value of our interest rate swaps; and

the recognition of a note payable and related other current asset pertaining to insurance.

Non-cash investing and financing activities for the year ended December 31, 2007 included:

adjustments to property, plant and equipment, goodwill and intangible assets resulting from the final purchase price allocations related to the St. James crude oil storage facility acquisition in December 2006;

the recognition of a note payable and related other current asset pertaining to insurance; and

adjustments to the fair value of our interest rate swap agreements.

Non-cash investing activities for the year ended December 31, 2006 included adjustments mainly to property, plant and equipment and goodwill resulting from the final purchase price allocation related to the Kaneb Acquisition in July 2005.

Cash flows related to interest and income taxes were as follows:

 

   

Year Ended December 31,

   

2008

  

2007

  

2006

   (Thousands of Dollars)

Cash paid for interest, net of amount capitalized

  $  98,810  $  83,450  $  73,206

Cash paid for income taxes, net of tax refunds received

  $12,231  $9,081  $7,234

   Year Ended December 31,
   2009  2008  2007
   (Thousands of Dollars)

Cash paid for interest, net of amount capitalized

  $  93,632  $  98,810  $  83,450

Cash paid for income taxes, net of tax refunds received

  $20,150  $  12,231  $9,081

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

23.21. INCOME TAXES

Components of income tax expense related to certain of our operations conducted through separate taxable wholly owned corporate subsidiaries were as follows:

 

  

Year Ended December 31,

   Year Ended December 31, 
  

2008

 

2007

 

2006

   2009 2008 2007 
  (Thousands of Dollars)    (Thousands of Dollars) 

Current:

           

U.S.

  $1,059  $2,373  $245   

$

 2,424   $  1,059   $  2,373  

Foreign

   9,910   8,799   5,690    10,144    9,910    8,799  
                       

Total current

   10,969   11,172   5,935    12,568    10,969    11,172  
                       

Deferred:

           

U.S.

   (1,280)  827   (3,681)   (1,466  (1,280  827  

Foreign

   1,317   (551)  3,607    (571  1,317    (551
                       

Total deferred

   37   276   (74)   (2,037  37    276  
                       

Total income tax expense

  $  11,006  $  11,448  $5,861   

$

 10,531   $  11,006   $  11,448  
                       

The difference between income tax expense recorded in our consolidated statements of income and income taxes computed by applying the statutory federal income tax rate (35% for all years presented) to income before income tax expense is due to the fact that the majority of our income is not subject to federal income tax due to our status as a limited partnership.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

The tax effects of significant temporary differences representing deferred income tax assets and liabilities were as follows:

 

   

December 31,

 
   

2008

  

2007

 
   (Thousands of Dollars) 

U.S.:

   

Net operating losses

  $23,283  $21,509 

Environmental and legal reserves

   14,252   14,611 

Other

   902   784 

Valuation allowance

   (13,366)  (13,276)
         

Deferred tax assets – U. S.

   25,071   23,628 
         

Property, plant and equipment

   (12,644)  (13,006)
         

Net deferred income tax asset – U.S.

  $12,427  $10,622 
         

Foreign:

   

Other

  $1,022  $1,057 

Capital loss

   1,569   2,292 

Valuation allowance

   (1,312)  (1,977)
         

Deferred tax assets – foreign

   1,279   1,372 
         

Property, plant and equipment

   (28,649)  (35,568)
         

Net deferred income tax liability – foreign

  $(27,370) $(34,196)
         

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

  December 31, 
    2009    2008 
    (Thousands of Dollars) 

U.S.:

    

  Net operating losses

 $ 20,788   $ 23,283  

  Environmental and legal reserves

  14,234    14,252  

  Other

  1,525    902  

  Valuation allowance

  (9,457  (13,366
        

    Deferred tax assets – U. S.

  27,090    25,071  
        

  Property, plant and equipment

  (13,197  (12,644
        

      Net deferred income tax asset – U.S.

 $ 13,893   $ 12,427  
        

Foreign:

    

  Net operating losses

 $ 3,253   $ -  

  Other

  687    1,022  

  Capital loss

  2,166    1,569  

  Valuation allowance

  -    (1,312
        

    Deferred tax assets – foreign

  6,106    1,279  
        

Property, plant and equipment

  (33,015  (28,649
        

      Net deferred income tax liability – foreign

 $ (26,909 $ (27,370
        

Our U.S. corporate operations have net operating loss carryforwards for tax purposes totaling approximately $66.5$59.4 million, which are subject to various limitations on use and expire in years 20092010 through 2028.2029.

As of December 31, 2009 and 2008, and 2007, we have recorded a valuation allowance substantially all of which was recorded in conjunction with the allocation of the purchase price of the Kaneb Acquisition, due to uncertainties related toreduce our ability to utilize some of ournet U.S. deferred income tax assets, primarily consistingasset to an amount that is more-likely-than-not to be realized. We estimate the amount of certain federal net operating loss carryforwards, before they expire. The net change in the total valuation allowance for the year ended December 31, 2008 was a decrease of $0.6 million. The valuation allowance is based onupon our estimatesexpectations of taxable income in the various jurisdictions in which we operate and the period over which deferred income taxwe can utilize those future deductions. The valuation allowance reflects uncertainties related to our ability to utilize certain federal net operating loss carryforwards before they expire. In 2009, we reduced the valuation allowance for both the U.S. net operating loss and the foreign capital loss assets by $5.2 million due to changes in our estimates of the amount of those loss carryforwards that will be recoverable.realized, based upon future taxable income and potential tax planning strategies.

The realization of net deferred income tax assets recorded as of December 31, 20082009 is dependent upon our ability to generate future taxable income in the United States. We believe it is more-likely-than not that the deferred income tax assets, net of the valuation allowance, as of December 31, 20082009 will be realized, based on expected future taxable income and potential tax planning strategies.

St. Eustatius Tax Agreement

On June 1, 1989, the governments of the Netherlands Antilles and St. Eustatius approved a Free Zone and Profit Tax Agreement retroactive to January 1, 1989, which expired on December 31, 2000. This agreement required a subsidiary of Kaneb, which we acquired on July 1, 2005, to pay the greater of 2% of taxable income, as defined therein, or 500,000 Netherlands Antilles guilders (approximately $0.3 million) per year. The agreement further provided that any amounts paid in order to meet the minimum annual payment were available to offset future tax liabilities under the agreement to the extent that the minimum annual payment is greater than 2% of taxable income.

On February 22, 2006, we entered into a revised agreement (the 2005 Tax and Maritime Agreement) with the governments of St. Eustatius and the Netherlands Antilles. The 2005 Tax and Maritime Agreement is effective beginning January 1, 2005 and expires on December 31, 2014. Under the terms of the 2005 Tax and Maritime Agreement, we

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

agreed to make a one-time payment of five5.0 million Netherlands Antilles guilders (approximately $2.8 million) in full and final settlement of all of our liabilities, taxes, fees, levies, charges, or otherwise (including settlement of audits) due or potentially due to St. Eustatius. We further agreed to pay an annual minimum profit tax to St. Eustatius of one1.0 million Netherlands Antilles guilders (approximately $0.6 million), beginning as of January 1, 2005. We agreed to pay the minimum annual profit tax in twelve equal monthly installments. To the extent the minimum annual profit tax exceeds 2% of taxable profit (as defined in the 2005 Tax and Maritime Agreement), we can carry forward that excess to offset future tax liabilities. If the minimum annual profit tax is less than 2% of taxable profit, we agreed to pay that difference.

24.22. SEGMENT INFORMATION

Beginning in the second quarterOur reportable segments consist of 2008, we revised the manner in which we internally evaluate our segment performancestorage, transportation, and made certain organizational changes. As a result, we have changed the way we report our segmental results. All product sales and related costs, including those associated with the East Coast Asphalt Operations, are included in the asphalt and fuels marketing segment. Also, the refined product terminals and crude oil storage tanks segments have been combined into the storage segment and the refined products pipelines and crude oil pipelines segments have been combined into the transportation segment. Previous periods have been restated to conform to this presentation.

marketing. Our segments represent strategic business units that offer different services. We evaluate the performance of each segment based on its respective operating income, before general and administrative expenses.expenses and certain non-segmental depreciation and amortization expense. General and administrative expenses are not allocated to the operating segments since those expenses relate primarily to the overall management at the entity level. Product sales included in ourOur principal operations include terminalling and storage of petroleum products, the transportation of petroleum products and anhydrous ammonia, and asphalt and fuels marketing segment consist of sales of asphalt and other petroleum products to third parties.marketing. Intersegment revenues are derivedresult from storage and throughput agreements at lease rates consistent with rates charged to third parties for storage and at pipeline tariffs based upon the published tariff applicable to all shippers.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

Results of operations for the reportable segments were as follows:

 

 Year Ended December 31, 
  

Year Ended December 31,

  2009 2008 2007 
  

2008

 

2007

 

2006

  (Thousands of Dollars) 
  (Thousands of Dollars) 

Revenues:

          

Storage:

          

Third party revenues

  $423,730  $400,058  $355,144  $ 444,535   $ 423,730   $ 400,058  

Intersegment revenues

   30,359   10,569   8,269   43,037    30,359    10,569  
                      

Total storage

   454,089   410,627   363,413   487,572    454,089    410,627  

Transportation:

          

Third party revenues

   316,900   296,565   281,010   300,814    316,900    296,565  

Intersegment revenues

   878   231   -   1,256    878    231  
                      

Total transportation

   317,778   296,796   281,010   302,070    317,778    296,796  

Asphalt and fuels marketing:

          

Third party revenues

   4,088,140   778,391   501,107   3,110,522    4,088,140    778,391  

Intersegment revenues

   29   -   -   -    29    -  
                      

Total asphalt and fuels marketing

   4,088,169   778,391   501,107   3,110,522    4,088,169    778,391  

Consolidation and intersegment eliminations

   (31,266)  (10,800)  (8,269)  (44,293  (31,266  (10,800
                      

Total revenues

  $  4,828,770  $  1,475,014  $  1,137,261  $ 3,855,871   $ 4,828,770   $ 1,475,014  
                      

Depreciation and amortization expense:

          

Storage

  $66,706  $62,317  $53,121  $ 70,888   $ 66,706   $ 62,317  

Transportation

   50,749   49,946   47,145   50,528    50,749    49,946  

Asphalt and fuels marketing

   14,734   423   -   19,463    14,734    423  

Consolidation and intersegment eliminations

   3,520   1,607   - 
            

Total segment depreciation and amortization expense

  140,879    132,189    112,686  

Other depreciation and amortization expense

  4,864    3,520    1,607  
                      

Total depreciation and amortization expense

  $135,709  $114,293  $100,266  $ 145,743   $ 135,709   $ 114,293  
            
          

Operating income:

          

Storage

  $141,079  $114,635  $108,486  $ 171,245   $ 141,079   $ 114,635  

Transportation

   135,086   126,508   122,714   139,869    135,086    126,508  

Asphalt and fuels marketing

   112,506   21,111   26,915   60,629    112,506    21,111  

Consolidation and intersegment eliminations

   (2,168)  (1,740)  -   1,170    1,352    (133
                      

Total segment operating income

   386,503   260,514   258,115   372,913    390,023    262,121  

Less general and administrative expenses

   76,430   67,915   45,216   94,733    76,430    67,915  

Less other depreciation and amortization expense

  4,864    3,520    1,607  
                      

Total operating income

  $310,073  $192,599  $212,899  $ 273,316   $ 310,073   $ 192,599  
                      

Revenues by geographic area for the years ended December 31, 2008, 2007 and 2006 are shown in the table below.

 

 Year Ended December 31, 
  

Year Ended December 31,

 2009 2008 2007 
  

2008

  

2007

  

2006

 (Thousands of Dollars) 
  (Thousands of Dollars)

United States

  $  3,731,685  $655,013  $501,756 

$

 2,971,961   $ 3,731,685   $ 655,013  

Netherlands Antilles

   926,690   719,084   537,626  693,808    926,690    719,084  

Canada

   97,762   44,927   51,203  106,989    97,762    44,927  

Other countries

   72,633   55,990   46,676  83,113    72,633    55,990  
                     

Consolidated revenues

  $  4,828,770  $  1,475,014  $  1,137,261 

$

 3,855,871   $ 4,828,770   $ 1,475,014  
                     

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

For the yearyears ended December 31, 2009 and 2008, no single customer accounted for more than 10% of our consolidated revenues. For the yearsyear ended December 31, 2007, and 2006, revenues from Valero Energy accounted for 18% and 23% of our consolidated revenues, respectively, and no other single customer accounted for more than 10% of our consolidated

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

revenue. As such, revenuesRevenues from Valero Energy by operating segment are presented only for the years ended December 31, 2007 and 2006were as follows:

 

   

Year Ended December 31,

   

2007

  

2006

   (Thousands of Dollars)

Revenues:

    

Storage

  $      115,417  $      100,069

Transportation

  147,597  160,911

Asphalt and fuels marketing

  7,426  -
      

Total revenues

  $      270,440  $      260,980
      

Year Ended

December 31, 2007

(Thousands of Dollars)

Revenues:

  Storage

$

115,417

  Transportation

147,597

  Asphalt and fuels marketing

7,426

    Total revenues

$

270,440

Long-lived assets include property, plant and equipment, intangible assets subject to amortization and certain long-lived assets included in “Other long-term assets, net” in the consolidated balance sheets. Geographic informationTotal amounts of long-lived assets by country for long-lived assets consisted of the following:were as follows:

 

 December 31,
  

December 31,

 2009  2008
  

2008

  

2007

 (Thousands of Dollars)
  (Thousands of Dollars)

United States

  $  2,630,940  $  2,109,594 

$

 2,667,559  $ 2,630,940

Netherlands Antilles

   253,355   252,024  252,030   253,355

Netherlands

  126,545   121,977

Canada

   80,956   95,618  93,801   80,956

United Kingdom

   70,335   92,149  83,144   70,335

Netherlands

   121,977   90,157

Mexico

   9,218   11,392  9,133   9,218
             

Consolidated long-lived assets

  $3,166,781  $2,650,934 

$

 3,232,212  $ 3,166,781
             

Total assets by reportable segment were as follows:

 

 December 31,
  

December 31,

 2009  2008
  

2008

  

2007

 (Thousands of Dollars)
  (Thousands of Dollars)

Storage

  $  2,140,010  $  2,085,345 

$

 2,234,651  $ 2,140,010

Transportation

   1,327,666   1,373,597  1,286,533   1,327,666

Asphalt and fuels marketing

   885,492   202,151  1,121,448   885,492
             

Total segment assets

   4,353,168   3,661,093  4,642,632   4,353,168

Other partnership assets

   106,429   121,994  132,041   106,429
             

Total consolidated assets

  $4,459,597  $3,783,087 

$

 4,774,673  $ 4,459,597
             

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

Changes in the carrying amount of goodwill were as follows:

 

   

Storage

  Transportation  Asphalt and
Fuels
Marketing
  

Total

 
   (Thousands of Dollars) 

Balance as of January 1, 2007

  $566,487  $  176,831  $  31,123  $  774,441 

St. James Acquisition final purchase price allocation

   13,898   -   -   13,898 

Other

   (1,856)  (1,464)  -   (3,320)
                 

Balance as of December 31, 2007

   578,529   175,367   31,123   785,019 
                 

East Coast Asphalt Operations acquisition preliminary purchase price allocation

   -   -   20,201   20,201 

Other

   1,110   -   -   1,110 
                 

Balance as of December 31, 2008

  $  579,639  $  175,367  $  51,324  $806,330 
                 

The 2007 amounts above have been revised to reflect goodwill relating to the bunkering activities at St. Eustatius and Point Tupper in the asphalt and fuels marketing segment.

  Storage  Transportation  Asphalt and
Fuels
Marketing
  Total 
  (Thousands of Dollars) 

Balance as of January 1, 2008

 $  578,529  $  175,367   $  31,123  $  785,019  

East Coast Asphalt Operations acquisition preliminary purchase price allocation

  -   -    20,201   20,201  

Other

  1,110   -    -   1,110  
                

Balance as of December 31, 2008

 $  579,639  $  175,367   $  51,324  $  806,330  
                

East Coast Asphalt Operations acquisition final purchase price allocation

  -   -    1,931   1,931  

Sale of assets

  -   (519  -   (519
                

Balance as of December 31, 2009

 $  579,639  $  174,848   $  53,255  $  807,742  
                

Capital expenditures, including acquisitions and investments in other noncurrent assets, by reportable segment were as follows:

 

 

Year Ended December 31,

  

Year Ended December 31,

 

2009

  

2008

  

2007

  

2008

  

2007

  

2006

   (Thousands of Dollars)
  (Thousands of Dollars)

Storage

  $191,696  $203,177  $230,416 $  137,050  $  191,696  $  203,177

Transportation

   23,117   25,344   54,678  27,551   23,117   25,344

Asphalt and fuels marketing

   787,733   1,755   -  21,458   787,733   1,755

Other partnership assets

   9,808   21,037   4,222  22,708   9,808   21,037
                    

Total capital expenditures

  $  1,012,354  $  251,313  $  289,316 $  208,767  $  1,012,354  $  251,313
                    

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

25.23. CONDENSED CONSOLIDATING FINANCIAL STATEMENTS

NuStar Energy has no operations and its assets consist mainly of its investments in NuStar Logistics and NuPOP, both wholly owned subsidiaries. The senior notes issued by NuStar Logistics and NuPOP are fully and unconditionally guaranteed by NuStar Energy, and both NuStar Logistics and NuPOP fully and unconditionally guarantee the outstanding senior notes of the other. As a result, the following condensed consolidating financial statements are being presented as an alternative to providing separate financial statements for NuStar Logistics and NuPOP.

Condensed Consolidating Balance SheetSheets

December 31, 20082009

(Thousands of Dollars)

 

 

NuStar

Energy

  

NuStar

Logistics

  NuPOP  Non-Guarantor
Subsidiaries (a)
 Eliminations Consolidated
 

NuStar
Energy

 

NuStar
Logistics

 

NuPOP

 

Non-Guarantor
Subsidiaries (a)

 

Eliminations

 

Consolidated

Assets

                     

Cash and cash equivalents

 $53 $2 $656 $44,664 $-  $45,375 $ 53  $  1,602  $  -  $  60,351   $  -   $  62,006

Receivables, net

  8  33,620  8,421  143,141  (6,974)  178,216  -   38,973   6,771   176,778    (10,725  211,797

Inventories

  -  -  347  220,937  (710)  220,574  -   -   -   379,472    (2,242  377,230

Other current assets

  9  9,472  13,673  19,167  -   42,321  -   10,746   3,820   69,120    -    83,686

Intercompany receivable

  -  337,685  666,052  -  (1,003,737)  -  -   806,005   713,451   -    (1,519,456  -
                                    

Current assets

  70  380,779  689,149  427,909  (1,011,421)  486,486  53   857,326   724,042   685,721    (1,532,423  734,719
                                    

Property, plant and equipment, net

  -  954,487  629,091  1,358,246  -   2,941,824  -   947,895   626,698   1,453,603    -    3,028,196

Intangible assets, net

  -  2,771  -  48,933  -   51,704  -   2,247   -   41,880    -    44,127

Goodwill

  -  18,613  170,652  617,065  -   806,330  -   18,094   170,652   618,996    -    807,742

Investment in wholly owned subsidiaries

  2,341,184  82,435  806,706  1,679,065  (4,909,390)  -  2,986,970   118,299   873,422   1,907,118    (5,885,809  -

Investments in joint
ventures

  -  -  -  68,813  -   68,813  -   -   -   68,728    -    68,728

Deferred income tax asset

  -  -  -  12,427  -   12,427  -   -   -   13,893    -    13,893

Other long-term assets, net

  56  34,557  26,517  30,883  -   92,013  49   21,942   26,392   28,885    -    77,268
                                    

Total assets

 $2,341,310 $1,473,642 $2,322,115 $4,243,341 $(5,920,811) $4,459,597 $ 2,987,072  $  1,965,803  $  2,421,206  $  4,818,824   $  (7,418,232 $  4,774,673
                                    

Liabilities and Partners’ Equity

                     

Current portion of long-term debt

 $- $713 $- $- $-  $713 $ -  $  770  $  -  $  -   $  -   $  770

Payables

  -  23,900  10,171  122,307  (6,974)  149,404  944   18,566   10,654   196,805    (10,725  216,244

Notes payable

  -  22,120  -  -  -   22,120  -   20,000   -   -    -    20,000

Accrued interest payable

  -  13,830  8,490  176  -   22,496  -   12,996   8,490   43    -    21,529

Accrued liabilities

  1,032  14,998  5,076  16,365  (17)  37,454  1,191   14,380   4,652   44,472    (44  64,651

Taxes other than income
taxes

  125  3,866  2,687  8,655  -   15,333

Income taxes payable

  -  976  -  3,528  -   4,504

Taxes other than income tax

  125   4,183   2,280   8,946    -    15,534

Income tax payable

  -   1,271   -   (1,245  -    26

Intercompany payable

  118,890  -  -  884,847  (1,003,737)  -  507,654   -   -   1,011,806    (1,519,460  -
                                    

Current liabilities

  120,047  80,403  26,424  1,035,878  (1,010,728)  252,024  509,914   72,166   26,076   1,260,827    (1,530,229  338,754
                                    

Long-term debt, less current portion

  -  1,309,763  531,504  30,748  -   1,872,015  -   1,271,750   523,326   33,917    -    1,828,993

Long-term payable to related party

  -  -  -  6,645  -   6,645  -   1,082   -   6,581    -    7,663

Deferred tax liability

  -  -  -  27,370  -   27,370  -   -   -   26,909    -    26,909

Other long-term liabilities

  -  4,992  965  88,589  -   94,546  -   3,923   883   82,580    -    87,386

Total partners’ equity

  2,221,263  78,484  1,763,222  3,054,111  (4,910,083)  2,206,997  2,477,158   616,882   1,870,921   3,408,010    (5,888,003  2,484,968
                                    

Total liabilities and partners’ equity

 $    2,341,310 $    1,473,642 $    2,322,115 $    4,243,341 $(5,920,811) $    4,459,597 $ 2,987,072  $  1,965,803  $  2,421,206  $  4,818,824   $  (7,418,232 $  4,774,673
                                    

 (a)

Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

Condensed Consolidating Balance SheetSheets

December 31, 20072008

(Thousands of Dollars)

 

  

NuStar
Energy

  

NuStar
Logistics

  

NuPOP

  

Non-Guarantor
Subsidiaries (a)

  

Eliminations

 

Consolidated

 

NuStar
Energy

 

NuStar
Logistics

 

NuPOP

 

Non-Guarantor
Subsidiaries (a)

 

Eliminations

 

Consolidated

Assets

                             

Cash and cash equivalents

  $7  $12,284  $122  $77,425  $-  $89,838 $   53 $   2 $   656 $   44,664 $   -   $   45,375

Receivables, net

   -   24,234   10,703   96,203   -   131,140   8   33,620   8,421   143,141   (6,974   178,216

Inventories

   -   -   -   88,664   (132)  88,532   -   -   347   220,937   (710   220,574

Other current assets

   9   4,606   15,889   17,120   -   37,624   9   9,472   13,673   19,167   -     42,321

Intercompany receivable

   -   39,238   646,226   -   (685,464)  -   -   337,685   666,052   -   (1,003,737   -
                                           

Current assets

   16   80,362   672,940   279,412   (685,596)  347,134   70   380,779   689,149   427,909   (1,011,421   486,486
                                           

Property, plant and equipment, net

   -   942,297   667,132   882,657   -   2,492,086   -   954,487   629,091   1,358,246   -     2,941,824

Intangible assets, net

   -   3,551   -   44,211   -   47,762   -   2,771   -   48,933   -     51,704

Goodwill

   -   18,613   170,652   595,754   -   785,019   -   18,613   170,652   617,065   -     806,330

Investment in wholly owned subsidiaries

   2,327,401   1,721   730,663   1,458,721   (4,518,506)  -   2,341,184   82,435   806,706   1,679,065   (4,909,390   -

Investments in joint ventures

   -   16,640   -   63,726   -   80,366   -   -   -   68,813   -     68,813

Deferred income tax asset

   -   -   -   10,622   -   10,622   -   -   -   12,427   -     12,427

Other long-term assets, net

   75   15,761   382   3,880   -   20,098   56   34,557   26,517   30,883   -     92,013
                                           

Total assets

  $2,327,492  $1,078,945  $2,241,769  $3,338,983  $(5,204,102) $3,783,087 $   2,341,310 $   1,473,642 $   2,322,115 $   4,243,341 $   (5,920,811 $   4,459,597
                                           

Liabilities and Partners’ Equity

                             

Current portion of long-
term debt

  $-  $663  $-  $-  $-  $663

Current portion of long-term debt

 $   - $   713 $   - $   - $   -   $   713

Payables

   -   22,273   5,532   135,504   -   163,309   -   23,900   10,171   122,307   (6,974   149,404

Notes payable

   -   22,120   -   -   -     22,120

Accrued interest payable

   -   8,986   8,490   249   -   17,725   -   13,830   8,490   176   -     22,496

Accrued liabilities

   1,570   16,469   13,135   16,072   (57)  47,189   1,032   14,998   5,076   16,365   (17   37,454

Taxes other than income
taxes

   126   3,249   2,873   3,909   -   10,157

Income taxes payable

   -   2,025   -   1,417   -   3,442

Taxes other than income tax

   125   3,866   2,687   8,655   -     15,333

Income tax payable

   -   976   -   3,528   -     4,504

Intercompany payable

   357,851   -   -   327,613   (685,464)  -   118,890   -   -   884,847   (1,003,737   -
                                           

Current liabilities

   359,547   53,665   30,030   484,764   (685,521)  242,485   120,047   80,403   26,424   1,035,878   (1,010,728   252,024
                                           

Long-term debt, less
current portion

   -   865,105   538,893   41,628   -   1,445,626   -   1,309,763   531,504   30,748   -     1,872,015

Long-term payable to related party

   -   -   -   5,684   -   5,684   -   -   -   6,645   -     6,645

Deferred income tax liability

   -   -   -   34,196   -   34,196   -   -   -   27,370   -     27,370

Other long-term liabilities

   -   3,984   1,520   54,760   -   60,264   -   4,992   965   88,589   -     94,546

Total partners’ equity

   1,967,945   156,191   1,671,326   2,717,951   (4,518,581)  1,994,832   2,221,263   78,484   1,763,222   3,054,111   (4,910,083   2,206,997
                                           

Total liabilities and partners’ equity

  $2,327,492  $1,078,945  $2,241,769  $3,338,983  $(5,204,102) $3,783,087 $   2,341,310 $   1,473,642 $   2,322,115 $   4,243,341 $   (5,920,811 $   4,459,597
                                           

(a)

Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Condensed Consolidating Statements of Income

For the Year Ended December 31, 2009

(Thousands of Dollars)

  

NuStar
Energy

  

NuStar
Logistics

  

NuPOP

  

Non-Guarantor
Subsidiaries (a)

  

Eliminations

  

Consolidated

 

Revenues

 $   -   $   297,929   $   153,268   $   3,441,422   $   (36,748 $   3,855,871  

Costs and expenses

   2,006     184,330     112,161     3,319,305     (35,247   3,582,555  
                              

    Operating income

   (2,006   113,599     41,107     122,117     (1,501   273,316  

Equity earnings in subsidiaries

   226,881     35,864     91,716     155,481     (509,942   -  

Equity earnings from joint ventures

   -     -     -     9,615     -     9,615  

Interest expense, net

   -     (51,715   (24,168   (3,501   -     (79,384

Other (expense) income, net

   -     23,078     (957   9,738     -     31,859  
                              

    Income before income tax expense

   224,875     120,826     107,698     293,450     (511,443   235,406  

Income tax expense

   -     1,332     -     9,199     -     10,531  
                              

    Net income

 $   224,875   $   119,494   $   107,698   $   284,251   $   (511,443 $   224,875  
                              

(a)Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

Condensed Consolidating Statements of Income

For the Year Ended December 31, 2008

(Thousands of Dollars)

 

  

NuStar
Energy

 

NuStar
Logistics

 

NuPOP

 

Non-Guarantor
Subsidiaries(a)

 

Eliminations

 

Consolidated

  

NuStar
Energy

 

NuStar
Logistics

 

NuPOP

 

Non-Guarantor
Subsidiaries (a)

 

Eliminations

 

Consolidated

 

Revenues

  $-  $298,003  $157,067  $4,386,481  $(12,781) $4,828,770  $   -   $   298,003   $   157,067   $   4,386,481   $   (12,781 $   4,828,770  

Costs and expenses

   1,628   181,216   116,057   4,231,959   (12,163)  4,518,697    1,628     181,216     116,057     4,231,959     (12,163   4,518,697  
                                                 

Operating income

   (1,628)  116,787   41,010   154,522   (618)  310,073    (1,628   116,787     41,010     154,522     (618   310,073  

Equity earnings in subsidiaries

   255,725   80,760   76,044   133,243   (545,772)  -    255,725     80,760     76,044     133,243     (545,772   -  

Equity earnings from joint ventures

   -   609   -   7,421   -   8,030    -     609     -     7,421     -     8,030  

Interest expense, net

   -   (61,792)  (24,704)  (4,322)  -   (90,818)   -     (61,792   (24,704   (4,322   -     (90,818

Other (expense) income, net

   (79)  28,668   (453)  9,603   -   37,739    (79   28,668     (453   9,603     -     37,739  
                                                 

Income before income tax expense

   254,018   165,032   91,897   300,467   (546,390)  265,024    254,018     165,032     91,897     300,467     (546,390   265,024  

Income tax expense

   -   752   -   10,254   -   11,006    -     752     -     10,254     -     11,006  
                                                 

Net income

  $254,018  $164,280  $91,897  $290,213  $(546,390) $254,018  $   254,018   $   164,280   $   91,897   $   290,213   $   (546,390 $   254,018  
                                                 

 

(a)

Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

Condensed Consolidating Statements of Income

For the Year Ended December 31, 2007

(Thousands of Dollars)

 

  

NuStar
Energy

 

NuStar
Logistics

 

NuPOP

 

Non-Guarantor
Subsidiaries (a)

  

Eliminations

 

Consolidated

  

NuStar
Energy

 

NuStar
Logistics

 

NuPOP

 

Non-Guarantor
Subsidiaries (a)

 

Eliminations

 

Consolidated

 

Revenues

  $-  $274,001  $149,973  $1,059,813  $(8,773) $1,475,014  $   -   $   274,001   $   149,973   $   1,059,813 $   (8,773 $   1,475,014  

Costs and expenses

   1,966   170,961   108,277   1,009,913   (8,702)  1,282,415    1,966     170,961     108,277     1,009,913   (8,702   1,282,415  
                                                

Operating income

   (1,966)  103,040   41,696   49,900   (71)  192,599    (1,966   103,040     41,696     49,900   (71   192,599  

Equity earnings in subsidiaries

   152,264   (12,500)  61,867   107,659   (309,290)  -    152,264     (12,500   61,867     107,659   (309,290   -  

Equity earnings from joint ventures

   -   738   -   6,095   -   6,833    -     738     -     6,095   -     6,833  

Interest (expense) income, net

   -   (52,036)  (25,173)  693   -   (76,516)   -     (52,036   (25,173   693   -     (76,516

Other income, net

   -   29,105   178   9,547   -   38,830    -     29,105     178     9,547   -     38,830  
                                                

Income before income tax expense

   150,298   68,347   78,568   173,894   (309,361)  161,746    150,298     68,347     78,568     173,894   (309,361   161,746  

Income tax expense

   -   2,026   -   9,422   -   11,448    -     2,026     -     9,422   -     11,448  
                                                

Net income

  $150,298  $66,321  $78,568  $164,472  $(309,361) $150,298  $   150,298   $   66,321   $   78,568   $   164,472 $   (309,361 $   150,298  
                                                

 

(a)

Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

Condensed Consolidating Statements of IncomeCash Flows

For the Year Ended December 31, 20062009

(Thousands of Dollars)

 

   

NuStar
Energy

  

NuStar
Logistics

  

NuPOP

  

Non-Guarantor
Subsidiaries (a)

  

Eliminations

  

Consolidated

 

Revenues

  $-  $261,929  $121,835  $754,509  $(1,012) $1,137,261 

Costs and expenses

   2,260   145,453   89,984   687,677   (1,012)  924,362 
                         

Operating income

   (2,260)  116,476   31,851   66,832   -   212,899 

Equity earnings in subsidiaries

   151,790   154   65,321   72,423   (289,688)  - 

Equity earnings from joint ventures

   -   815   -   5,067   -   5,882 

Interest expense, net

   -   (37,145)  (25,093)  (4,028)  -   (66,266)

Other income, net

   -   1,242   19   1,991   -   3,252 
                         

Income from continuing operations before income tax expense

   149,530   81,542   72,098   142,285   (289,688)  155,767 

Income tax expense

   -   -   -   5,861   -   5,861 
                         

Income from continuing operations

   149,530   81,542   72,098   136,424   (289,688)  149,906 

Income (loss) from discontinued operations

   -   -   317   (693)  -   (376)
                         

Net income

  $149,530  $81,542  $72,415  $135,731  $(289,688) $149,530 
                         
    

NuStar
Energy

    

NuStar
Logistics

    

NuPOP

    

Non-

Guarantor
Subsidiaries

(a)

    

Elim-
inations

    

Consolidated

 

Net cash provided by (used in) operating activities

 $  263,017   $  103,753   $  70,433   $  32,302   $  (288,923 $  180,582  
                        

Cash flows from investing activities:

            

Capital expenditures

  -    (49,800  (23,734  (135,022  -    (208,556

Investment in subsidiaries

  (295,178  -    -    (30  295,208    -  

Proceeds from sale or disposition of assets

  -    29,215    108    357    -    29,680  

Proceeds from insurance settlement

  -    -    -    11,382    -    11,382  

Investment in other noncurrent assets

  -    -    -    (211  -    (211
                        

Net cash used in investing activities

  (295,178  (20,585  (23,626  (123,524  295,208    (167,705
                        

Cash flows from financing activities:

            

Debt borrowings

  -    1,608,188    -    -    -    1,608,188  

Debt repayments

  -    (1,641,119  -    -    -    (1,641,119

Issuance of common units, net of issuance costs

  288,761    -    -    -    -    288,761  

General partner contribution

  6,155    -    -    -    -    6,155  

Partners’ contributions

  -    295,178    -    30    (295,208  -  

Distributions to unitholders and general partner

  (263,896  (263,896  -    (25,027  288,923    (263,896

Net intercompany (repayments) borrowings

  1,141    (80,506  (47,483  126,848    -    -  

Other, net

  -    (1,982  20    1,201    -    (761
                        

Net cash (used in) provided by financing activities

  32,161    (84,137  (47,463  103,052    (6,285  (2,672
                        

Effect of foreign exchange rate changes on cash

  -    2,569    -    3,857    -    6,426  

Net increase (decrease) in cash and cash equivalents

  -    1,600    (656  15,687    -    16,631  

Cash and cash equivalents as of the beginning of year

  53    2    656    44,664    -    45,375  
                        

Cash and cash equivalents as of the end of year

 $  53   $  1,602   $  -   $  60,351   $  -   $  62,006  
                        

 

(a)

Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

Condensed Consolidating StatementStatements of Cash Flows

For the Year Ended December 31, 2008

(Thousands of Dollars)

 

    

NuStar
Energy

    

NuStar
Logistics

    

NuPOP

    

Non-

Guarantor
Subsidiaries

(a)

    

Elim-
inations

    

Consolidated

 

Net cash provided by (used in) operating activities

 $  239,707   $  111,078   $  34,487   $  341,873   $  (241,964 $  485,181  
                        

Cash flows from investing activities:

            

Capital expenditures

  -    (51,575  (14,009  (136,559  -    (202,143

Acquisition of East Coast Asphalt Operations

  -    -    -    (803,184  -    (803,184

Other acquisitions

  -    (7,027  -    -    -    (7,027

Proceeds from sale or disposition of assets

  -    40,396    1    10,416    -    50,813  

Proceeds from insurance settlement

  -    -    -    5,000    -    5,000  

Other, net

  -    -    -    24    -    24  
                        

Net cash used in investing activities

  -    (18,206  (14,008  (924,303  -    (956,517
                        

Cash flows from financing activities:

            

Debt borrowings

  -    2,855,575    -    -    -    2,855,575  

Debt repayments

  -    (2,761,821  -    -    -    (2,761,821

Senior note offering, net

  -    346,224    -    -    -    346,224  

Issuance of common units, net of issuance costs

  236,215    -    -    -    -    236,215  

General partner contribution

  5,025    -    -    -    -    5,025  

Distributions to unitholders and general partner

  (241,940  (241,940  -    (24  241,964    (241,940

Net intercompany (repayments) borrowings

  (238,961  (298,292  (19,945  557,198    -    -  

Other, net

  -    440    -    345    -    785  
                        

Net cash (used in) provided by financing activities

  (239,661  (99,814  (19,945  557,519    241,964    440,063  
                        

Effect of foreign exchange rate changes on cash

  -    (5,340  -    (7,850  -    (13,190

Net increase (decrease) in cash and cash equivalents

  46    (12,282  534    (32,761  -    (44,463

Cash and cash equivalents as of the beginning of year

  7    12,284    122    77,425    -    89,838  
                        

Cash and cash equivalents as of the end of year

 $  53   $  2   $  656   $  44,664   $  -   $  45,375  
                        

 

(a)

Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

Condensed Consolidating StatementStatements of Cash Flows

For the Year Ended December 31, 2007

(Thousands of Dollars)

 

    

NuStar
Energy

    

NuStar
Logistics

    

NuPOP

    

Non-

Guarantor
Subsidiaries

(a)

    

Elim-
inations

    

Consolidated

 

Net cash provided by (used in) operating activities

 $  195,640   $  139,631   $  34,566   $  50,188   $  (197,353 $  222,672  
                        

Cash flows from investing activities:

            

Capital expenditures

  -    (65,653  (15,689  (169,909  -    (251,251

Proceeds from sale of assets

  -    66    15    12,586    -    12,667  

Other, net

  -    (58  -    246    -    188  
                        

Net cash used in investing activities

  -    (65,645  (15,674  (157,077  -    (238,396
                        

Cash flows from financing activities:

            

Debt borrowings

  -    1,170,302    -    -    -    1,170,302  

Debt repayments

  -    (1,077,975  -    -    -    (1,077,975

Issuance of common units, net of issuance costs

  143,083    -    -    -    -    143,083  

General partner contribution

  3,035    -    -    -    -    3,035  

Distributions to unitholders and general partner

  (197,333  (197,333  -    (20  197,353    (197,333

Net intercompany (repayments) borrowings

  (144,555  35,613    (19,762  128,704    -    -  

Other, net

  -    (3,144  -    (908  -    (4,052
                        

Net cash provided by (used in) financing activities

  (195,770  (72,537  (19,762  127,776    197,353    37,060  
                        

Effect of foreign exchange rate changes on cash

  -    (1,510  -    1,174    -    (336

Net (decrease) increase in cash and cash equivalents

  (130  (61  (870  22,061    -    21,000  

Cash and cash equivalents as of the beginning of year

  137    12,345    992    55,364    -    68,838  
                        

Cash and cash equivalents as of the end of year

 $  7   $  12,284   $  122   $  77,425   $  -   $  89,838  
                        

 

(a)

Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

 

Condensed Consolidating Statement of Cash Flows

For the Year Ended December 31, 2006

(Thousands of Dollars)

  

NuStar
Energy

  

NuStar
Logistics

  

NuPOP

  

Non-

Guarantor

Subsidiaries

(a)

  

Elim-
inations

  

Consolidated

 

Net cash provided by (used in) operating activities

 $178,687  $116,929  $17,992  $  120,512  $  (183,309) $250,811 
                        

Cash flows from investing activities:

      

Capital expenditures

  -   (33,939)  (12,276)  (77,807)  -   (124,022)

Proceeds from sale of assets

  -   15   2   71,379   -   71,396 

Acquisition and investment in other long-term assets

  -   (156,275)  (50)  (8,969)  -   (165,294)

Other, net

  (77)  (7,099)  27,112   (22,527)  7,277   4,686 
                        

Net cash (used in) provided by investing activities

  (77)  (197,298)  14,788   (37,924)  7,277   (213,234)
                        

Cash flows from financing activities:

      

Debt borrowings

  -   269,026   -   -   -   269,026 

Debt repayments

  -   (83,510)  -   -   -   (83,510)

Distributions to unitholders and general partner

  (183,290)  (183,290)  -   (19)  183,309   (183,290)

Net intercompany borrowings (repayments)

  4,232   95,075   (31,902)  (67,405)  -   - 

Other, net

  575   (6,177)  -   6,754   (7,277)  (6,125)
                        

Net cash (used in) provided by financing activities

  (178,483)  91,124   (31,902)  (60,670)  176,032   (3,899)
                        

Effect of foreign exchange rate changes on cash

  -   -   -   (894)  -   (894)

Net increase in cash and cash equivalents

  127   10,755   878   21,024   -   32,784 

Cash and cash equivalents as of the beginning of year

  10   1,590   114   34,340   -   36,054 
                        

Cash and cash equivalents as of the end of year

 $137  $12,345  $992  $55,364  $-  $68,838 
                        

(a)

Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

NUSTAR ENERGY L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

26.24. QUARTERLY FINANCIAL DATA (UNAUDITED)

 

  

First

Quarter

  

Second
Quarter

  

Third
Quarter

  

Fourth
Quarter

  

Total

 First
Quarter
   Second
Quarter
   Third
Quarter
 Fourth
Quarter
   Total
  (Thousands of Dollars, Except Per Unit Data) (Thousands of Dollars, Except Per Unit Data)

2008:

          

2009:

        

Revenues

  $  592,774  $  1,377,580  $  1,825,226  $  1,033,190  $  4,828,770 $  634,004 $  987,842 $  1,251,247 $982,778 $  3,855,871

Operating income

   65,186   40,362   175,478   29,047   310,073  55,434  84,076  87,190  46,616  273,316

Net income

   55,869   14,090   151,277   32,782   254,018  39,355  83,735  64,440  37,345  224,875

Net income per unit applicable to limited partners

   1.01   0.15   2.60   0.47   4.22  0.58  1.38  1.03  0.50  3.47

Cash distributions per unit applicable to limited partners

   0.985   0.985   1.0575   1.0575   4.085  1.0575  1.0575  1.0650  1.0650  4.245

2007:

          

2008:

        

Revenues

  $296,824  $321,032  $397,017  $460,141  $1,475,014 $592,774 $  1,377,580 $  1,825,226 $1,033,190 $  4,828,770

Operating income

   45,435   42,086   60,361   44,717   192,599  65,186  40,362  175,478  29,047  310,073

Net income

   31,123   39,697   51,213   28,265   150,298  55,869  14,090  151,277  32,782  254,018

Net income per unit applicable to limited partners

   0.57   0.74   0.97   0.47   2.74

Net income per unit applicable to limited partners (a)

  1.01  0.15  2.60  0.46  4.22

Cash distributions per unit applicable to limited partners

   0.915   0.950   0.985   0.985   3.835  0.985  0.985  1.0575  1.0575  4.085

(a)In 2008, the FASB provided additional guidance regarding the application of the two-class method to calculate earnings per unit for master limited partnerships, which was effective January 1, 2009. As a result, net income per unit applicable to limited partners for the fourth quarter 2008 changed from $0.47 previously reported.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

ITEM 9.CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

None.

 

ITEM 9A.CONTROLS AND PROCEDURES

DISCLOSURE CONTROLS AND PROCEDURES.

Our management has evaluated, with the participation of the principal executive officer and principal financial officer of NuStar GP, LLC, the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934 (the Exchange Act)) as of the end of the period covered by this report, and has concluded that our disclosure controls and procedures were operating effectively as of December 31, 2008.2009.

INTERNAL CONTROL OVER FINANCIAL REPORTING.

(a)  Management’s Report on Internal Control over Financial Reporting.

(a)Management’s Report on Internal Control over Financial Reporting.

Management’s report on NuStar Energy L.P.’s internal control over financial reporting required by Item 9A. appears in Item 8. of this report, and is incorporated herein by reference.

(b)  Attestation Report of the Registered Public Accounting Firm.

(b)Attestation Report of the Registered Public Accounting Firm.

The report of KPMG LLP on NuStar Energy L.P.’s internal control over financial reporting appears in Item 8. of this Form 10-K, and is incorporated herein by reference.

(c)  Changes in Internal Controls over Financial Reporting.

(c)Changes in Internal Controls over Financial Reporting.

There has been no change in our internal control over financial reporting that occurred during our last fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

 

ITEM 9B.OTHER INFORMATION

None.

PART III

ITEM 10.  DIRECTORS, AND EXECUTIVE OFFICERS OF THE REGISTRANTAND CORPORATE GOVERNANCE

DIRECTORS AND EXECUTIVE OFFICERS OF NUSTAR GP, LLC

We do not have directors or officers. The directors and officers of NuStar GP, LLC, the general partner of our general partner, Riverwalk Logistics, L.P., perform all of our management functions. NuStar GP Holdings, LLC (NuStar GP Holdings), the sole member of NuStar GP, LLC, selects the directors of NuStar GP, LLC.LLC (the Board). Officers of NuStar GP, LLC are appointed by its directors.

Set forth below is certain information concerning the directors and executive officers of NuStar GP, LLC:

 

Name

 

Age

 

Position Held with NuStar GP, LLC

William E. Greehey

 7273 Chairman of the Board

Curtis V. Anastasio

 5253 President, Chief Executive Officer (CEO) and Director

J. Dan Bates

 6465 Director

Dan J. Hill

 6869 Director

Stan McLelland

 6364 Director

Rodman D. Patton

 6566 Director

Bradley C. Barron

 4344 Senior Vice President and General Counsel and Secretary

Steven A. Blank

 5455 Senior Vice President, Chief Financial Officer (CFO) and Treasurer

James R. Bluntzer

 5455 Senior Vice President-Operations

Mary F. MorganPaul W. Brattlof

 5648 Senior Vice President- European OperationsPresident-Trading and Supply

Mary Rose Brown

53Senior Vice President-Administration

Daniel S. Oliver

43Vice President-Marketing and Business Development

Thomas R. Shoaf

 5051 Vice President and Controller

As a limited partnership, we are not required by the NYSE rules to have a nominating committee, and the Board has historically performed the functions served by a nominating committee. In accordance with our Corporate Governance Guidelines, individuals are considered for membership on the Board based on their character, judgment, integrity, diversity, age, skills (including financial literacy), independence and experience in the context of the overall needs of the Board. Our directors are also selected based on their knowledge about our industry and their respective experience leading or advising large companies. We require that our directors have the ability to work collegially, exercise good judgment and think critically. In addition, we ask that our directors commit to working hard for our company. The Board strives to find the best possible candidates to represent the interests of NuStar Energy L.P. and its unitholders. As part of its self-assessment process, the Board annually evaluates the mix of independent and non-independent directors, the selection and functions of the presiding director and whether the Board has the appropriate range of talents, expertise and backgrounds.

The Board is led by its Chairman, Mr. Greehey. The Board has determined that separating the roles of Chairman and CEO is in the best interest of unitholders at this time. In addition, the Board has appointed Mr. Patton as its presiding director to serve as a point of contact for unitholders wishing to communicate with the Board and to lead executive sessions of the non-management directors.

Mr. Greeheybecame Chairman of the board of directors of NuStar GP, LLC (the Board)the Board in January 2002. He has also been the Chairman of the board of directors of NuStar GP Holdings since March 2006. Mr. Greehey served as Chairman of the board of directors of Valero Energy Corporation (Valero Energy) from 1979 through January 2007. Mr. Greehey was CEO of Valero Energy from 1979 through December 2005, and President of Valero Energy from 1998 until January 2003.

Mr. Anastasiobecame the President and a director of NuStar GP, LLC in December 1999. He also became its CEO in June 2000. Mr. Anastasio has also served as President and CEOChief Executive Officer of NuStar GP Holdings since March 2006, and he has been a director of NuStar GP Holdings since January 2007.

Mr. Batesbecame a director of NuStar GP, LLC in April 2006. He has been President and CEO of the Southwest Research Institute since 1997. Mr. Bates also serves as Chairman of the board of Signature Science L.L.C. and Vice Chairman of Southwest Automotive Research Center. He served as Vice Chairman of the board of directors of the Federal Reserve Bank of Dallas’ San Antonio Branch and as Chairman of the board of directors of Signature Science L.L.C. and Vice Chairman of Southwest Automotive Research Center.from January 2005 through December 2009.

Mr. Hillbecame a director of NuStar GP, LLC in July 2004. From February 2001 through May 2004, he served as a consultant to El Paso Corporation. Prior to that, he served as President and CEO of Coastal Refining and Marketing Company. In 1978, Mr. Hill was named as Senior Vice President of The Coastal Corporation and President of Coastal States Crude Gathering. In 1971, he began managing Coastal’s NGL business. Previously, Mr. Hill worked for Amoco and Mobil.

Mr. McLelland became a director of NuStar GP, LLC in October 2005. He has also served as a director of NuStar GP Holdings since July 2006. Mr. McLelland has served as a director of two privately held companies, Patton Surgical Corp. and the general partner of Yorktown Technologies, LP, since November 2003 and June 2004, respectively. Mr. McLelland was U. S.U.S. Ambassador to Jamaica from January 1997 until March 2001. Prior to being named U.S. Ambassador to Jamaica, Mr. McLelland was a senior executive with Valero Energy. He joined Valero Energy in 1981

as Senior Vice President and General Counsel, and he served as Executive Vice President and General Counsel from 1990 until 1997.

Mr. Patton became a director of NuStar GP, LLC in June 2001. He retired from Merrill Lynch & Co. in 1999 where he had served as Managing Director in the Energy Group since 1993. Prior to that, he served in investment banking and corporate finance positions with Credit Suisse First Boston (1981-1993) and Blyth Eastman Paine Webber (1971-1981). He ishas also served as a director of Apache Corporation.Corporation since 1999 and is a member of its audit committee.

Mr. Barronbecame Senior Vice President and General Counsel of NuStar GP, LLC and NuStar GP Holdings in April 2007. He also served as Secretary of NuStar GP, LLC and NuStar GP Holdings LLC infrom April 2007.2007 to February 2009. He served as Vice President, General Counsel and Secretary of NuStar GP, LLC from January 2006 until his promotion in April 2007. Mr. Barron has also served as Vice President, General Counsel and Secretary of NuStar GP Holdings from March 2006 until his promotion in April 2007. HeMr. Barron served as Managing Counsel and Corporate Secretary of NuStar GP, LLC from July 2003 until January 2006. From January 2001 until July 2003, he served as Counsel, and then Senior Counsel, to Valero Energy.

Mr. Blankbecame Senior Vice President and CFO of NuStar GP, LLC in January 2002, and he became NuStar GP, LLC’s Treasurer as well in July 2005. He has also served as Senior Vice President, CFO and Treasurer of NuStar GP Holdings since March 2006. From December 1999 until January 2002, he was Chief Accounting and Financial Officer and a director of NuStar GP, LLC. He served as Vice President and Treasurer of Ultramar Diamond Shamrock Corporation from December 1996 until January 2002.

Mr. Bluntzerbecame Senior Vice President-Operations of NuStar GP, LLC in October 2005. He served as Vice President-Operations of NuStar GP, LLC from February 2004 until October 2005. He served as Vice President-Terminal Operations of NuStar GP, LLC from May 2003 to February 2004. He served as Special Projects Director of NuStar GP, LLC from January 2002 to May 2003 and as Vice President of Midstream Operations of Valero Energy from June 2001 to January 2002. He served as Refinery Logistics & Supply Chain Director of Valero Energy from July 2000 to June 2001.

Ms. MorganMr. Brattlofbecame Senior Vice President- European OperationsPresident-Trading and Supply of NuStar GP, LLC in April 2007. Previously, Mr. Brattlof served in various positions, including Vice President-Trading, for Valero Energy from May 1997 through April 2007.

Ms. Brown became Senior Vice President-Administration of NuStar GP, LLC in April 2008. She served as Senior Vice President-Corporate Communications from April 2007 through April 2008. Prior to her service to NuStar GP, LLC, Ms. Brown served as Senior Vice President-Corporate Communications for Valero Energy from September 1997 to April 2007.

Mr. Oliver became Vice President-Marketing and Business Development of NuStar GP, LLC in October 2008. Previously, she served as Senior Vice President- Marketing and Business Development of NuStar GP, LLC from April 2007 until October 2008. Ms. Morgan served as Vice President- Marketing and Business Development of NuStar GP, LLC from July 2005 until April 2007. Ms. MorganPrior to that, Mr. Oliver served as Vice President for NuStar Marketing and Business Development of Kaneb Pipe Line Company LLC from 2004 until July 2005. SheLLC. Previously, Mr. Oliver served as Vice President, Marketing of Kinder MorganPresident-Product Supply & Distribution for Valero Energy Partners, L.P. from 1998 until 2004.May 1997 to July 2007.

Mr. Shoaf became Vice President and Controller of NuStar GP, LLC in July 2005. He has also served as Vice President and Controller of NuStar GP Holdings since March 2006. Mr. Shoaf served as Vice President-Structured Finance offor Valero Corporate Services Company, a subsidiary of Valero Energy, from 2001 until his appointment with NuStar GP, LLC.

COMPLIANCE WITH SECTION 16(a) OF THE EXCHANGE ACT

Section 16(a) of the Exchange Act requires directors, executive officers and persons who beneficially own more than 10% of NuStar Energy L.P.’s equity securities to file certain reports with the Securities and Exchange Commission (SEC) concerning their beneficial ownership of NuStar Energy’s equity securities within two business days. We believe that during the year ended December 31, 20082009 all Section 16(a) reports applicable to our executive officers, directors and greater than 10% stockholders were timely filed.filed, with the exception of an inadvertent omission of 907 units from the Form 3 for Mr. Brattlof (which was subsequently corrected on Form 5 filed on February 10, 2010) and the filing of Ms. Brown’s and Mr. Oliver’s Forms 3 one day late. In addition, Mr. Bluntzer filed a Form 5 on February 24, 2010 to report the acquisition of an aggregate 40 common units that were purchased pursuant to a dividend reinvestment program administered by his securities broker.

CODE OF ETHICS OF SENIOR FINANCIAL OFFICERS

NuStar GP, LLC has adopted a Code of Ethics for Senior Financial Officers that applies to NuStar GP, LLC’s principal executive officer, principal financial officer and controller. This code charges the senior financial officers with responsibilities regarding honest and ethical conduct, the preparation and quality of the disclosures in documents and reports NuStar GP, LLC files with the SEC and compliance with applicable laws, rules and regulations.

CORPORATE GOVERNANCE

AUDIT COMMITTEE

The Audit Committee reviews and reports to the Board on various auditing and accounting matters, including the quality, objectivity and performance of NuStar Energy’s internal and external accountants and auditors, the adequacy of its financial controls and the reliability of financial information reported to the public. The Audit Committee also monitors NuStar Energy’s compliance with environmental laws and regulations. The Board has adopted a written charter for the Audit Committee. The members of the Audit Committee during 20082009 were Rodman D. Patton (Chairman), J. Dan Bates and Dan J. Hill. The Audit Committee met eight times in 2008.2009. For further information, see the“Report of the Audit Committee” below.

The Board has determined that Mr. Patton is an “audit committee financial expert” (as defined by the SEC), and that he is “independent” as that term is used in the New York Stock Exchange (NYSE)NYSE Listing Standards.

REPORT OF THE AUDIT COMMITTEE FOR FISCAL YEAR 20082009

Management of NuStar GP, LLC is responsible for NuStar Energy’s internal controls and the financial reporting process. KPMG LLP (KPMG), NuStar Energy’s independent registered public accounting firm for the year ended December 31, 2008,2009, is responsible for performing an independent audit of NuStar Energy’s consolidated financial statements in accordance with the standards of the Public Company Accounting Oversight Board (PCAOB) and generally accepted auditing standards, and an audit of NuStar Energy’s internal control over financial reporting in accordance with the standards of the PCAOB, and issuing a report thereon. The Audit Committee monitors and oversees these processes and approves the selection and appointment of NuStar Energy’s independent registered public accounting firm and recommends the ratification of such selection and appointment to the Board.

The Audit Committee has reviewed and discussed NuStar Energy’s audited consolidated financial statements with management and KPMG. The Audit Committee has discussed with KPMG the matters required to be discussed by Statement on Auditing Standards No. 61, “Communications with Audit Committees.114, as adopted by the PCAOB. The Audit Committee

has received written confirmationdisclosures and the letter from KPMG required by applicable requirements of the firm’sAudit Committee concerning independence from KPMG and has discussed with KPMG that firm’s independence.

Based on the foregoing review and discussions and such other matters the Audit Committee deemed relevant and appropriate, the Audit Committee recommended to the Board that the audited consolidated financial statements of NuStar Energy be included in NuStar Energy’s Annual Report on Form 10-K for the year ended December 31, 2008.2009.

Members of the Audit Committee:

Rodman D. Patton (Chairman)

J. Dan Bates

Dan J. Hill

RISK OVERSIGHT

While it is the job of management to assess and manage our risk, the Board of Directors and its Audit Committee (each where applicable) discuss the guidelines and policies that govern the process by which risk assessment and management is undertaken and evaluate reports from various functions with the management team on risk assessment and management. The Board interfaces regularly with management and receives periodic reports that include updates on operational, financial, legal and risk management matters. The Audit Committee assists the Board in oversight of the integrity of NuStar Energy’s financial statements and NuStar Energy’s compliance with legal and regulatory requirements, including those related to the health, safety and environmental performance of our company. The Audit Committee also reviews and assesses the performance of NuStar Energy’s internal audit function and its independent auditors. The Board receives regular reports from the Audit Committee. We do not believe that the Board’s role in risk oversight has an effect on the Board’s leadership structure.

Evaluation of Compensation Risk. The Compensation Committee has focused on aligning our compensation policies with the long-term interests of NuStar Energy and avoiding short-term rewards for management decisions that could pose long-term risks to NuStar Energy. NuStar Energy’s compensation programs are structured so that a considerable amount of our management’s compensation is tied to NuStar Energy’s long-term fiscal health. The only short-term incentive available to NuStar Energy employees and executives is the all-employee performance bonus. All bonuses, including executive bonuses, are determined with reference to performance metrics selected by the Compensation Committee and applicable to all employees. Historically, our long-term incentives have taken the form of performance units, restricted units and unit options that typically vest over three- and five-year periods, thereby aligning our employees’ interests with the long-term goals of NuStar Energy. No business group or unit is compensated differently than any other, regardless of profitability. As such, we believe that our compensation policies encourage employees to operate our business in a fundamentally sound manner and do not create incentives to take risks that are reasonably likely to have a material adverse effect on NuStar Energy.

ITEM 11. EXECUTIVE COMPENSATION

COMPENSATION COMMITTEE REPORT

The Compensation Committee has reviewed and discussed the Compensation Discussion and Analysis with management. Based on the foregoing review and discussion and such other matters the Compensation Committee deemed relevant and appropriate, the Compensation Committee recommended to the Board that the Compensation Discussion and Analysis be included in this annual report.

Members of the Compensation Committee:

Dan J. Hill (Chairman)

J. Dan Bates

Rodman D. Patton

Members of the Compensation Committee:
Dan J. Hill (Chairman)
J. Dan Bates
Rodman D. Patton

COMPENSATION DISCUSSION AND ANALYSIS

Executive Compensation Philosophy

Our philosophy for compensating our named executive officers (as defined below)(NEO) is based on the belief that a significant portion of executive compensation should be incentive-based and determined by both NuStar Energy’s and the executive’s performance objectives. Our executive compensation programs are designed to accomplish the following long-term objectives:

 

increase value to unitholders, while practicing good corporate governance;

 

support our business strategy and business plan by clearly communicating what is expected of executives with respect to goals and results;

 

provide the Compensation Committee with the flexibility to respond to the continually changing environment in which NuStar Energy operates;

align executive incentive compensation with NuStar Energy’s short- and long-term performance results; and

 

provide market-competitive compensation and benefits to enable us to recruit, retain and motivate the executive talent necessary to be successful.produce sustainable, superior growth for our unitholders.

Compensation for our named executive officers primarily consists of base salary, an annual incentive bonus and long-term, equity-based incentives. Our named executive officers alsoexecutives participate in the same group benefit plans generallyprograms available to our other employees.salaried employees in the United States. In addition, see “Post-Employment Benefits” below in this Item 11. Our executives do not have employment or severance agreements, other than the change-of-control agreements described below in “Potential Payments Upon Termination or Change of Control.” The Compensation Committee’s philosophy for 2008 was to targetCommittee targets base salary for our named executive officers, (as defined below), as well as annual incentive bonus and long-term incentive awards (expressed, in each case, as a percentage of base salary), at or near the median of theour peer group and after reviewing survey data we use in our evaluations.for a group of 825 industrial companies. In each case, an executive’s salary and incentive opportunities wereare determined by the unique responsibilities of his or her position and by theeach executive’s experience and performance.performance, with the market information in mind.

Throughout this Item 11, the individuals serving as our principal executive officer and our principal financial officer during the last completed fiscal year (Curtis V. Anastasio and Steven A. Blank, respectively) and our three other most highly compensated executive officers who were serving as executive officers at the end of the last completed fiscal year (Bradley C. Barron, James(James R. Bluntzer, Paul W. Brattlof and Mary F. Morgan)Rose Brown) are referred to collectively as the “named executive officers.”officers” or NEOs.

Administration of Executive Compensation Programs

Our executive compensation programs are administered by our Board’s Compensation Committee. The Compensation Committee is composed of three independent directors who are not participants in our executive compensation programs. Policies adopted by the Compensation Committee are implemented by our compensation and benefits staff.

Annually, the Compensation Committee reviews market trends in compensation, including the practices of identified competitors, and the alignment of the compensation program with NuStar Energy’s strategy. Specifically, for executive officers, the Compensation Committee:

establishes and approves target compensation levels for each executive officer;

approves individual executive and company-level performance measures and goals;

determines the mix between cash and equity compensation, short-term and long-term incentives and benefits;

verifies the achievement of previously established performance goals; and

approves the resulting cash or equity awards to executives.

In making determinations about total compensation for executives, the Compensation Committee takes into account a number of factors, including: the competitive market for talent; NuStar Energy’s performance; the particular executive’s role, responsibilities, experience and performance; and retention. The Compensation Committee also considers other equitable factors such as the role, contribution and performance of an individual executive relative to the executive’s peers at the company. The Compensation Committee does not assign specific weight to these factors, but rather makes a subjective judgment taking all of these factors into account.

The Compensation Committee has retained BDO Seidman, LLP (BDO) as its independent compensation consultant with respect to executive compensation matters. In its role as advisor to the Compensation Committee, BDO was retained directly by the Compensation Committee, which has the authority to select, retain and/or terminate its relationship with a consulting firm.

Selection of Compensation Comparative Data

In 2008,2009, the Compensation Committee relied upon two primary sources of competitive compensation data in assessing the rates of base salary rates, annual incentive compensation and long-term incentive compensation: a group of master limited partnerships and other companies in our industry and broader survey data on comparably sized entities.

To establish compensation for the named executive officers, including the CEO, the Committee, in consultation with management and BDO, identified a specific group of 15 master limited partnerships and three independent, regional refining companies to evaluate competitive rates of compensation (the Compensation Comparative Group). The three refining companies, Frontier Oil Corporation, Holly Corporation and Western Refining Inc., were added to our prior peer list last year to account for our acquisition of asphalt refining and marketing assets from CITGO Asphalt Refining Company in March 2008. Each of these organizations is in our industry, and, in our opinion, competes with us for executive talent. The competitive data for these master limited partnershipscompanies is derived from their respective publicly filed annual proxy statements or annual reports on Form 10-K. The 20082009 data was compiled and analyzed by BDO.

 

Company

  

Ticker

1.

Boardwalk Pipeline Partners

  BWP

2.

Buckeye Partners LP

  BPL

3.

Copano Energy LLC

  CPNO

4.

Crosstex Energy LP

  XTEX

5.

Enbridge Energy Partners LP

  EEP

6.

Energy Transfer Partners

  ETP

7.

Enterprise Product Partners LP

  EPD

8.

Kinder Morgan Energy LP

  KMP

9.

Magellan Midstream Partners LP

  MMP

10.

Mark West Energy Partners

  MWE

11.

ONEOK Partners, L.P.

  OKS

12.

Plains All American Pipeline LP

  PAA

13.

Regency Energy Partners

  RGNC

14.

Sunoco Logistics Partners LP

  SXL

15.

Teppco Partners LP

  TPP

16.

Frontier Oil Corporation*

  FTO

17.Holly Corporation*

  HOC

18.

Western Refining Inc.*

  WNR

* Added in 2008.

The Compensation Committee also reviewed survey data reported by BDO on a position-by-position basis to ascertain additional information regarding compensation of comparable positions. The survey data consists of general industry data for executive positions reported in the Towers Perrin Executive Compensation General Industry database, a proprietary compensation database of an approximate 825 U.S. industrial companies that is updated each year. At our request, BDO employedreviewed and interpreted the tabular data from the Towers Perrin survey reported for companies in a range of reported revenues comparable to NuStar Energy’s. We refer to the competitive survey data, together with the Compensation Comparative Group data, as the Compensation Comparative Data.

Process and Timing of Compensation Decisions

The Compensation Committee reviews and approves all compensation for the named executive officers. Recommendations regarding compensation for named executive officers other than the CEO are developed by the CEO in consultation with BDO. In making these recommendations, the CEO takes into consideration the Compensation

Comparative Data and evaluates the individual performance of each named executive officer and their respective contributions to the Company. The recommendations are then reviewed by the Compensation Committee, which may accept the recommendations or may make adjustments to the recommended compensation based on their own assessment of the individual’s performance and contributions to NuStar Energy.

As required by the Compensation Committee’s charter, the compensation of the CEO is reviewed and approved by the Compensation Committee based on the Compensation Comparative Data andData; discretionary adjustments may be made based upon their independent evaluation of the CEO’s performance and contributions.

Each July, the Compensation Committee reviews the named executive officers’ total compensation, including base salary and the target levels of annual incentive and long-term incentive compensation. Its review includes a comparison with competitive market data provided by BDO, an evaluation of the total compensation of the executive officer group from an internal equity perspective and reviews of reports on the compensation history of each executive. Based on these reviews and evaluations, the Compensation Committee establishes annual salary rates for executive officer positions for the upcoming 12-month period and sets target levels of annual incentive and long-term incentive compensation. Although the target levels are established in July, the long-term incentives are reviewed again at the time of grant, typically in the fourth quarter for unit options and restricted units and in the first quarter for performance units. The Compensation Committee may also review salaries or grant long-term incentive awards at other times during the year because of new appointments, promotions or other extraordinary circumstances.

The following table summarizes the approximate timing of some of our more significant compensation events:

 

Event  Timing

Establishing financial performance objectives for current year’s annual incentive bonus; evaluating achievement of bonus metrics in prior year

 

  First quarter

Review and certify financial performance for performance units granted in prior years; grant performance units

 

  First quarter

Review base salaries for executive officers for the current year and targets for annual incentive bonus and long-term incentive grants

 

  Third quarter

Consider grant of restricted unit and unit options to employees and officers and grant restricted units to directors

  

Fourth quarter; three business days after third quarter earnings releases (or as soon as practicable thereafter)

Setting meeting dates for action by the Compensation Committee for the upcoming year  

Fourth quarter

Additional information regarding the timing of 20082009 long-term incentive grants is discussed below under “Performance Units” and “Restricted Units.”

Elements of Executive Compensation

General

Our executive compensation programs currently consist of the following material elements:

 

base salaries;

annual incentive bonuses;

long-term equity-based incentives, including:

performance units; and

restricted units;

unit options; and

medical and other insurance benefits, retirement benefits and other perquisites.

We chose these elements to remain competitive in attracting and retaining executive talent and to provide strong performance incentives that provide the potential for both current and long-term gains. We use base salary as the foundation for our executive compensation program. We believe that base salary should provide a fixed level of competitive pay that reflects the executive officer’s primary duties and responsibilities, as well as a foundation for incentive opportunities and benefit levels. Our annual incentive bonuses are designed to focus our executives on NuStar Energy’s attainment of key financial performance measures that we believe generate profitable annual operations and sustaining results.our distributable cash flow (DCF), which is widely regarded among the master limited partnership (MLP) investment community as a significant determinant of an MLP’s unit price. Our long-term equity incentive awards are designed to directly tie an executive’s financial reward opportunities with the rewards to unitholders, as measured by long-term unit price performance and payment of distributions. Throughout this Item 11, we use the term “Total Direct Compensation” to refer to the sum of an executive officer’s base salary, annual incentive bonus and long-term incentive awards for a particular fiscal year. We also offer group medical benefits that allow employees (including NEOs) affordable coverage at group rates, as well as pension benefits that reward continued service and a thrift plan that provides a tax-advantaged savings opportunity.

Relative Size of Primary Elements of Compensation

In setting executive compensation, the Compensation Committee considers the aggregate amount of compensation payable to an executive officer and the form of the compensation. The Compensation Committee seeks to achieve the appropriate balance between immediatesalary, cash rewards earned for the achievement of company and personal objectives and long-term incentives that align the interests of our executive officers with those of our unitholders. The size of each element is based on competitive market practices, as well as company and individual performance.

The level of incentive compensation typically increases in relation to an executive officer’s responsibilities, with the level of incentive compensation for more senior executive officers being a greater percentage of total compensation than for less senior executives. The Compensation Committee believes that making a significant portion of an executive officer’s incentive compensation contingent on long-term unit price performance more closely aligns the executive officer’s interests with those of our unitholders.

Because we place such a large proportion of our total executive compensation at risk in the form of variable pay (i.e. annual and long-term incentives), the Compensation Committee does not adjust current compensation based upon realized gains or losses from prior incentive awards. For example, we will not reduce the size of a target long-term incentive grant in a particular year solely because NuStar Energy’s unit price performed well during the immediately preceding years. We believe that adopting a policy of making such adjustments would penalize management’s current compensation for NuStar Energy’s prior success.

The following table summarizes the relative size of base salary and incentive compensation targets for 20082009 for each of our named executive officers:

Name  Target Percentage of Total Direct Compensation  

TOTAL

  Base Salary  Annual
Incentive Bonus
  Long-Term
Incentives
  

Curtis V. Anastasio

  30  24  46  100

Bradley C. Barron

  43  22  35  100

Steven A. Blank

  43  22  35  100

James R. Bluntzer

  43  22  35  100

Mary F. Morgan

  43  22  35  100
  Target Percentage of Total Direct Compensation  
Name Base Salary 

Annual

Incentive Bonus

 

 

Long-Term

Incentives

 TOTAL
Anastasio 30 24 46 100
Blank 43 22 35 100
Bluntzer 43 22 35 100
Brattlof 43 22 35 100
Brown 43 22 35 100

Individual Performance and Personal Objectives

The Compensation Committee evaluates our named executive officers’ individual performance and performancepersonal objectives with input from our CEO. Our CEO’s performance is evaluated by the Compensation Committee in consultation with other members of the Board.

Assessment of individual performance may include objective criteria, but is a largely subjective process. The criteria used to measure an individual’s performance may include use of quantitative criteria (e.g., execution of projects within budget, improving an operating unit’s profitability, or timely completion of an acquisition or divestiture), as well as more qualitative factors, such as the executive officer’s ability to lead, ability to communicate and successful adherence to NuStar’s core values (i.e., environmental and workplace safety, integrity, work commitment, effective communication and teamwork). There are no specific weights given to any of these various elements of individual performance.

We use our evaluation of individual performance to supplement our objective compensation criteria and adjust an executive officer’s recommended compensation. For example, although an individual officer’s indicated bonus may be calculated to be $100,000, an individual performance evaluation might result in a reduction to $90,000 or increase to $120,000 of that indicated bonus.

Base Salaries

The base salaries for our executive officers are reviewed annually by the Compensation Committee based on recommendations of our CEO, with input from BDO and our compensation and benefits staff. Our CEO’s base salary is reviewed and approved by the Compensation Committee based on its review of recommendations by BDO and our compensation and benefits staff.

The competitiveness of base salaries for each executive position is determined by an evaluation of the compensation data described above. Base salaries may be adjusted to achieve what is determined to be a reasonably competitive level or to reflect promotions, the assignment of additional responsibilities, individual performance or the performance of NuStar Energy. Salaries are also periodically adjusted to remain competitive with the Compensation Comparative Data.

Beginning inIn July 2008,2009, our named executive officers received the following adjustmentssame 3% adjustment to annualized base salaries which the Compensation Committee considered necessary to achieve a reasonably competitive salary level in each case:that was approved for all eligible employees.

 

Name    Annualized Base Salary      July 2008 Increase to Prior
  Annualized Base Salary
 Annualized Base Salary 

July 2009 Increase to Prior

Annualized Base Salary

Anastasio

  $460,000    $23,200 $473,800     $13,800

Barron

  265,000    31,000

Blank

  331,000    12,968 340,900     9,900

Bluntzer

  296,600    44,920 305,500     8,900

Morgan

  296,600    12,160
Brattlof 289,600     8,400
Brown 305,500     8,900

Annual Incentive Bonus

Our named executive officers participate in a formal annual incentive plan in which all domestic company employees participate. Under the plan, the named executive officers can earn annual incentive bonuses based on the following three factors:

The individual’s position, which is utilized to determine a targeted percentage of annual base salary that may be awarded as incentive bonus. Generally, the target amount for the named executive officers is set following the analysis of market practices in the Compensation Comparator Group and a determination of the median bonus target available to comparable executives in those companies;

NuStar Energy’s attainment of specific quantitative financial goals, which are established by the Compensation Committee during the first quarter of the year; and

A discretionary evaluation by the Compensation Committee of both NuStar Energy’s performance and, in the case of the named executive officers, the individual executive’s performance.

The following table shows the percentage of each named executive officer’s annual base salary that represents his or her annual bonus target for the fiscal year ended December 31, 2008,2009, before discretionary adjustments, as discussed below:

Name 

Annual Incentive Bonus Target

as a Percentage of Base Salary

Anastasio

 80

Barron

50

Blank

 50

Bluntzer

 50

MorganBrattlof

 50

Brown

 50

Determination of Annual Incentive Target Opportunities

As stated above, each named executive officer has an annual incentive opportunity generally based on a stated percentage of his or her base salary. This target proportion is the annual incentive award for achieving a 100% score on our stated financial goal under the bonus plan. For example, Mr. Anastasio has a target annual incentive opportunity equal to 80% of his base annual salary. Mr. Anastasio’s annual salary rate beginning July 20082009 was $460,000,$473,800, and therefore, his target annual incentive opportunity for a 100% score was $368,000.$379,040. In addition, the plan allows for the upward or downward adjustment of awards, based upon attainment of the financial goal, equal to a range of 0% to 200% of the target award. If we failed to reach at least the threshold level of performance for our financial goal, the participant would have earned an incentive award of $0. Likewise, if we had achieved the maximum level of performance for the financial goal, the participant could earn up to 200% of his target award.

Once the financial goals have been reviewed and measured, the Compensation Committee has the authority to exercise its discretion in evaluating NuStar Energy’s performance. In exercising this discretionary judgment, the Compensation Committee considers such relevant performance factors as growth, attainment of strategic objectives, acquisitions and divestitures, safety and environmental compliance, and other considerations. This discretionary judgment may result in an increase or decrease of as much as 25% of the aggregate earned award for all employees based upon the attainment of the financial goals noted above.

The CEO develops individual incentive bonus recommendations based upon the methodology described above. In addition, both the CEO and the Compensation Committee may make adjustments to the recommended incentive bonus amounts based upon an assessment of an individual’s performance and contributions to NuStar Energy. The CEO and the Compensation Committee also review and discuss each executive bonus on a case-by-case basis, considering such factors as teamwork, leadership, individual accomplishments and initiative, and may adjust the bonus awarded to reflect these factors.

The grant levelbonus target for the CEO is decided solely by the Compensation Committee, and the Compensation Committee may make discretionary adjustments to the calculated level of bonus based upon its independent evaluation of the CEO’s performance and contributions.

Company Performance Objectives

Prior to 2007, our annual all-employee incentive plan established performance goals in three principal financial areas:

NuStar Energy’s earnings per unit (EPU) compared to the target, threshold, and maximum performance levels, as established and approved by the Compensation Committee at the start of the plan year;

NuStar Energy’s total unitholder return (TUR), expressed as the total return to unitholders based upon the growth in the unit price as well as cash distributions to unitholders during the plan year, either (a) our TUR compared to a peer group or (b) as compared to a target, threshold, and maximum TUR established and approved by the Compensation Committee at the start of the plan year; and

NuStar Energy’s distributable cash flow (DCF) per unit (DCF Per Unit) compared to the target, threshold and maximum performance levels, as established and approved by the Compensation Committee at the start of the plan year.

In 2007, the Compensation Committee adopted DCF per unit (DCF Per Unit versus a targetUnit) as the sole 2007 bonus metric due to: (i) the nature of TUR as a long-term performance measure rather than as a bonus measure, (ii) the fact that management is already incentivized to focus on TUR through performance units, and (iii) anin acknowledgement that, in the master

limited partnership investment community, DCF is widely regarded as a significant determinant of unit price.price, and, as such, the Compensation Committee believes the measure appropriately focuses employees on improving DCF. In 2008, the Compensation Committee approved a change to a simple DCF metric, based on

management’s recommendations and input from BDO. Management’s recommendation to move to a simple DCF target rather than DCF Per Unit iswas based on the fact that an increase to the distribution reducesserves to reduce DCF Per Unit (but not DCF) due tothrough the operation of the incentive distribution rights held by our general partner, NuStar GP Holdings. We believe that basing bonus on DCF more properly aligns our management’s interest with our unitholders’ interest in continuously increasing distributions in a prudent manner.

In February 2008,We derive DCF from our financial statements by adjusting our net income for depreciation and amortization expense, equity earnings from joint ventures and unrealized gains and losses arising from certain derivative contracts. Additionally, we subtract our aggregate annual reliability capital expenditures and add the aggregate annual amount of cash distributions received from equity method investees.

Each year, the Compensation Committee establishedestablishes NuStar Energy’s budgeted DCF for the upcoming year as a target and establishedestablishes corresponding levels of performance for which the incentive opportunity would be paid, such that if less than 90% of the target was attained, no bonus would be paid; if 90% of the target was attained, 50% of the incentive opportunity could be paid; if the target was achieved, 100% of the incentive opportunity could be paid; if 110% of the target was attained, 150% of the incentive opportunity could be paid; and if 120% or more of the target was attained, 200% of the incentive opportunity could be paid. The budgeted DCF may be adjusted during the year to account for acquisitions or other significant changes not anticipated at the time the target was determined. In April 2008, the Compensation Committee adjusted the2009, NuStar’s budgeted DCF target for 2008 upward to take NuStar Energy’s acquisition of CARCO’s East Coast asphalt assets into consideration.was $355,000,000.

Determination of Awards

For the 20082009 annual incentive program,bonus determination, the Compensation Committee measured NuStar Energy’s DCF against the established target to determine the amount of incentive award earned. NuStar Energy’s DCF for 20082009 would have resulted in payment of 165% of the incentive opportunity. This score was then adjusted for extraordinary items, such as asset divestitures, and the resulting adjusted 2008 DCF would have resulted in payment of 118%65% of the incentive opportunity.

Upon reviewing the 118%65% performance score and upon management’s recommendation, the Compensation Committee exercised its discretionary judgment regarding the plan and further adjusted the performance score downwardupward to 100%75%. This resulted in each employee, including the named executive officers, having a potential annual incentive award equal to 100%75% of his or her target award. In making the 18% downward adjustment, the Compensation Committee took into consideration the overall42% increase in unit price decline during 2008 and balanced48% total unitholder return for 2009, the successful completion of the integration of our asphalt operations, NuStar Energy’s exceptional health and safety record, and our desire to recognize and reward our employees’ significant accomplishments with our commitment to fiscal discipline.accomplishments.

 

Name

 Bonuses Paid For 2008      2009

Anastasio

 $368,000  284,300
Blank 127,800

Barron

Bluntzer
 132,500  115,000
Brattlof 108,600

Blank

Brown
 165,500  

Bluntzer

148,000  

Morgan

148,000  115,000

Long-term Incentive Awards

We provide unit-based, long-term compensation for employees, including executives and directors, through our Second Amended and Restated 2000 Long-Term Incentive Plan (the 2000 LTIP), which was approved by our unitholders on September 18, 2006. In previous years, we have provided such compensation under the NuStar GP, LLC Amended and Restated 2002 Unit Option Plan and the NuStar GP, LLC Amended and Restated 2003 Employee Unit Incentive Plan. The 2000 LTIP provides for a variety of unit and unit-based awards, including unit options, restricted units and performance units. Performance units vest (become nonforfeitable) upon the achievement of an objective performance goal. Grants of restricted unit and unit options each vest over a period determined by the Compensation Committee.

Under the design of the long-term incentive award plan, each plan participant, including the named executive officers, are designated a target long-term incentive award expressed as a percentage of base salary. This percentage reflects the expected fair value of the awards to be granted in aggregate each year. In determining the expected fair value, BDO employed a projected value model to determine the value of long-term incentive grants, which requires first calculating

the value of an award by projecting the growth in the fair market value of a unit and then calculating the present value of the expected gain at the end of five years.

For the named executive officers, the 20082009 long-term incentive target percentages (expressed as a percent of base salary) were established as follows:shown in the table below.

 

Name 

Long-Term Incentive Target Percentage  

(% of base salary)

Anastasio

 150

Barron

Blank
 80

Blank

Bluntzer
 80

Bluntzer

Brattlof
 80

Morgan

Brown
 80

These target levels are based upontargets, as well as the allocation between time- and performance-based grants described below, reflect the Compensation Committee’s 2009 review of the Compensation Comparative Data provided by BDO and upondiscussion of the appropriate balance to best retain executives, align management with unitholder concerns and reward management for increases in unitholder value. The committee reviews these targets, as well as allocation between types of grants on at least an annual basis. At its meeting on February 26, 2010, after a discussion of the current Compensation Comparative Data and the factors described above, the Compensation Committee’s strategic decisionsCommittee determined it to allocatebe appropriate to raise the long-term incentive targets as follows: Mr. Anastasio 160%, Mr. Blank, Mr. Bluntzer and Ms. Brown, 100% and Mr. Brattlof, 90%.

The Compensation Committee allocates a percentage of long-term award value to performance-based awards and a percentage to awards that focus on retention and increasing ownership levels of executive officers. In 2008,2009, the target levels were allocated in the following manner for each individual:

 

30% of the targeted long-term incentive dollar value is awarded to the executive in a grant of performance units. The number of performance units granted is based upon the expected fair value of a single performance unit at the time of grant; and

70% of the targeted long-term incentive dollar value is awarded to the executive in the form of restricted units. The number of restricted units granted is based upon the expected fair value of a single performancerestricted unit at the time of grant.

Prior to 2007, we also awarded unit options to named executive officers and allocated awards of long-term components in approximate one-third increments among the three forms of awards: unit options, performance units and restricted units. In 2007, however, the Compensation Committee eliminated the grant of NuStar Energy unit options as a long-term incentive component and increased the percentage of restricted units granted. The Compensation Committee based its decision on the results of a comparison study of peer companies performed by its independent compensation consultant, BDO. This study showed that the use of three different forms of award in the executive long-term incentive program is not consistent with peer practice and may dilute the effectiveness of each component. The comparison also showed that, although the use of restricted units and performance units is consistent with peer practices, the use of unit options is not common among NuStar Energy’s peers as a recurring component of a long-term incentive compensation.

The Compensation Committee reviews and approves all grant levelsgrants for the named executive officers, as well as all other participants in the program. The CEO develops individual grant recommendations based upon the methodology described above, but both the CEO and the Compensation Committee may make adjustments to the recommended grant levelsgrants based upon an assessment of an individual’s performance and contributions to NuStar Energy. The grant level for the CEO is decided solely by the Compensation Committee following the methodology described above, and the Compensation Committee may make discretionary adjustments to the calculated levelnumber of long-term incentives to grant based upon its independent evaluation of the CEO’s performance and contributions.

Restricted Units

 

Name        Restricted Units Granted in 2008         
  NS  NSH   

Anastasio

  8,500  8,700  

Barron

  2,600  2,700  

Blank

  3,300  3,400  

Bluntzer

  2,900  3,000  

Morgan

  2,900  3,000  

Name  

 

Restricted Units Granted in 2009

  NS  NSH

Anastasio

  6,900  6,500

Blank

  2,645  2,495

Bluntzer

  2,370  2,235

Brattlof

  2,245  2,120

Brown

  2,370  2,235

In 2008, theThe restricted units comprisedcomprise approximately 70% of each executive’s total NuStar Energy long-term incentive target. The Compensation Committee presently expects to grant restricted units annually. Beginning in 2008, theThe executives’ long-term incentive targets includedinclude approximately 70% NuStar Energy L.P. restricted units and 30% NuStar GP Holdings LLC restricted units (in both cases, calculated from an assumed unit value based on the average closing price for the business days in the last two weeks of August 2008, approximately two months prior to the grant date,2009, and adjusted for the risk of forfeiture). The restricted units all vest in equal increments on the anniversary of the grant date over five years. Restricted units of NuStar GP Holdings LLC were introduced into the compensation program in 2008 to reflect the fact that the performance of NuStar GP Holdings is directly tied to the performance of NuStar Energy, due to the fact that NuStar GP Holdings’ sole asset is its interest in NuStar Energy. The restricted units all vest in equal increments on the anniversary of the grant date over five years. The grant of the NuStar GP Holdings LLC restricted units, as well as the grant of the NuStar Energy L.P. restricted units, were approved in a joint meeting of the Compensation Committee and the compensation committee of NuStar GP Holdings’ Board of Directors

In 2008,2009, the Compensation Committee and management made a determination that the grants for all employees, includingexcluding management and non-employee directors, would be made as soon as administratively practicable after the third business day following our third quarter earnings release.release, which was November 6, 2009. At the time the Compensation Committee approved the grants of restricted units, NuStar Energy’s Board had approved an equity offering of NuStar Energy units. Given the impending offering, the Committee determined that the grants to executive management, certain other employees and the non-employee directors would be delayed until December 14, 2009, which was thirty (30) calendar days after the closing date of the equity offering.

Performance Units

 

Name

 Performance Unit Grants in 2008        2009
Anastasio 6,383

Anastasio

Blank
 3,7002,400
Bluntzer 2,200

Barron

Brattlof
 1,4002,050
Brown 

Blank

1,700

Bluntzer

1,400

Morgan

1,4002,200

In 2008, performancePerformance units comprisedcomprise approximately 30% of each of our named executive officers’ total NuStar Energy long-term incentive targets. 2006 was the first year the Compensation Committee awarded performance units, and for our current program, theThe Compensation Committee expects to award performance units annually. Performance units are earned only upon NuStar Energy’s achievement of an objective performance measure, TUR,total unitholder return (TUR), as compared with a subset of the Compensation Comparative Group consisting of the first nine entities listed in the peer group table above. These nineNuStar Energy’s TUR is the total return to unitholders, based upon the growth in the unit price, as well as cash distributions to unitholders during the year. The entities selected most closely track with our size and business, making their TUR performance most comparable with ours (the Peer Group). Further, while the Compensation Comparative Group represents the market in which we compete for executive talent, the smaller group selected for purposes of measuring relative TUR is representative of the market in which we compete for capital. The Compensation Committee believes this type of incentive award strengthens the tie between the named executive’s pay and our financial performance.

The number of performance units granted is determined by multiplying annual base salary rate by the Long-Term Incentive Target Percentage, and then multiplying that product by 30%. That product is then divided by the assumed

value of an individual unit, which is the product of (x) the average unit price for the period of December 15 through December 31 (using the daily high and low prices) and (y) a factor that reflects the present value of the award and a risk that the award might be forfeited.

Each award is subject to vesting in three annual increments, based upon our TUR during rolling three-year periods that end on December 31 of each year following the date of grant. At the end of each performance period, our TUR is compared to the Peer Group and ranked by quartile. Executives then earn 0%, 50%, 100% or 150% of that portion of the initial grant amount that is vesting, depending upon whether our TUR is in the last, 3rd, 2nd or 1st quartile, respectively, and they earn 200% if we rank highest in the group. Amounts not earned in a given performance period can be carried forward for one additional performance period and up to 100% of the carried amount can still be earned, depending upon the quartile achieved for that subsequent period. For the performance period ended December 31, 2008,2009, our performance ranked third in the group, placing NuStar Energy in the thirdfourth quartile of the group for the rolling three-year period, which results in no vesting of the 20082009 performance units available to vest in 2010. Due to the fact that NuStar Energy generated a 48% total unitholder return for 2009 atalone, the 50% level. Additionally, based on NuStar Energy’s position inCommittee decided to carry forward the last quartile of the peer group for the performance period ended December 31, 2007, previously granted performance units that were availablewould have been forfeited for vesting in 2008 vested at 0%. Under

the terms of the performance unit grant agreements, the applicable performance units that failed to vest in 2008 carried over and vested in 2009 at the 50% level. The remaining 50% of the carried-forward performance units were forfeited.

Employment Agreements

On December 15, 2008, the Compensation Committee entered into an employment agreement (the Employment Agreement) and a retention bonus agreement (the Retention Agreement) with Ms. Morgan in connection with her appointment to the office of Senior Vice President – European Operations of the Company. Ms. Morgan will be seconded to the Company’s U.K. affiliates to oversee NuStar Energy’s European operations.

Under the Employment Agreement, beginning January 1, 2009, Ms. Morgan will receive an annual base salary of $320,000, to be adjusted as necessaryperiod for tax equalization purposes; an annual incentive bonus based upon achievement of certain performance measures established by the Compensation Committee each year; long-term incentive awards, including restricted units of NuStar Energy and/or NuStar Holdings, unit options of NuStar Energy and/or NuStar Holdings, and performance units of NuStar Energy, each as determined by the Compensation Committee each year; participation in the Company’s Excess Thrift Plan, to the extent applicable; and standard health and other benefits. The Employment Agreement includes terms related to protection of confidential information and 12-month non-competition and non-solicitation covenants. The Employment Agreement is for a term of two years.

Pursuant to the Retention Agreement, Ms. Morgan was paid a lump sum bonus in the amount of $500,000 (the Retention Bonus), pre-tax, in December 2008. If Ms. Morgan voluntarily terminates her employment or the Company terminates Ms. Morgan for “cause” (as defined in the Retention Agreement) prior to December 17, 2010, she will be required to pay back a portion of the Retention Bonus determined by a fraction, the numerator of which will be twenty-four (24) minus the number of full months Ms. Morgan was employed during the two-year period, and the denominator of which will be twenty-four (24).one additional year.

Perquisites and Other Benefits

Perquisites

In 2008, we providedWe provide only minimal perquisites to our executive officers. Mr. Anastasio receivesand Ms. Brown receive reimbursement for club membership dues. Mr. Anastasio, Mr. BarronBlank, Mr. Brattlof and Mr. Blank receiveMs. Brown received federal income tax preparation services.services in 2009. Executives are also eligible to receive liability insurance (personal liability insurance and coverage under NuStar Energy’s directors and officers liability insurance policies).insurance. For more information on perquisites, see the Summary Compensation Table and its footnotes.

Other Benefits

We provide other benefits, including medical, life, dental and disability insurance in line with competitive market conditions. Our named executive officers are eligible for the same benefit plans provided to our other employees, including our pension plan, 401(K) thrift plan (the Thrift PlanPlan) and insurance and supplemental plans chosen and paid for by employees who desire additional coverage.

Executive officers and other employees whose compensation exceeds certain limits are eligible to participate in non-qualified excess benefit programs whereby those individuals can choose to make larger contributions than allowed under the qualified plan rules and receive correspondingly higher benefits. These plans are described below under “–Post-Employment“Post-Employment Benefits.”

Post-Employment Benefits

Pension Plans

For a discussion of our pension plans, including the Excess Pension Plan and the Supplemental Executive Retirement Plan, please see the narrative description accompanying the Pension Benefits table below of this item.

Nonqualified Deferred Compensation Plans

Excess Thrift Plan

The Excess Thrift Plan provides unfunded benefits to those employees of NuStar GP, LLC whose annual additions under the NuStar GP, LLC Thrift Plan are subject to the limitations on such annual additions as provided under §415 of the Internal Revenue Code of 1986, as amended (the Code), and/or who are constrained from making maximum contributions under the Thrift Plan by §401(a)(17) of the Code, which limits the amount of an employee’s annual compensation which may be taken into account under that plan. The Excess Thrift Plan is comprised of two separate components, consisting of (1) an “excess benefit plan” as defined under §3(36) of The Employee Retirement Income Security Act of 1974, as amended (ERISA) and (2) a plan that is maintained primarily for the purpose of providing deferred compensation for a select group of management or highly compensated employees. Each component of the Excess Thrift Plan consists of a separate plan for purposes of Title I of ERISA. To the extent a participant’s annual total compensation exceeds the compensation limits for the calendar year under §401(a)(17) of the Code ($230,000245,000 for 2008)2009), the participant’s excess thrift plan account is credited with that number of hypothetical NuStar Energy L.P. units that could have been purchased with the difference between:

 

The total company matching contributions that would have been credited to the participant’s account under the NuStar GP, LLC Thrift Plan had the participant’s contributions not been reduced pursuant to §401; and

 

The actual company matching contributions credited to such participant’s account.

Mr. Anastasio, Mr. Barron, Mr. Blank, Mr. Bluntzer, Mr. Brattlof and Ms. MorganBrown participated in the Excess Thrift Plan in 2008.2009.

Frozen Nonqualified 401(k) Plan

Effective July 1, 2006, we established the NuStar GP, LLC Frozen Nonqualified 401(k) Plan for Former Employees of Ultramar Diamond Shamrock Corporation (the Frozen Plan). The Frozen Plan assumes and continues the frozen Ultramar Diamond Shamrock Corporation Nonqualified 401(k) Plan (the UDS Plan) with respect to the current NuStar GP, LLC employees who had accrued benefits under the UDS Plan. No additional benefits accrue under the Frozen Plan, and we make no contributions to the Frozen Plan. Mr. Anastasio and Mr. Blank have Frozen Plan accounts.

Change-of-Control Severance Arrangements

We have entered into change of control agreements with each of the named executive officers.officers in or prior to 2007. These agreements are intended to assure the continued availability of these executives in the event of certain transactions culminating in a “change of control” as defined in the agreements. The change of control employment agreements have three-year terms, which terms are automatically extended for one year upon each anniversary unless a notice not to extend is given by us. If a “change of control” (as defined in the agreements) occurs during the term of an agreement, then the agreement becomes operative for a fixed three-year period. The agreements provide generally that the executive’s terms and conditions of employment (including position, location, compensation and benefits) will not be adversely changed during the three-year period after a change of control of us. The agreements also provide that upon a change of control:

all unit options held by the executive will vest and remain exercisable for the shorter of five years from the date of termination or the remainder of the original option term;

the restrictions and deferral limitations applicable to any restricted unit awards held by the executive will lapse, and such restricted unit awards shall become fully vested; and

all performance unit awards held by the executive will fully vest and be earned and payable based on the deemed achievement of performance at 200% of target level.

Particular payments under the agreements are triggered commensurate with the occurrence of any of the following: (i) termination of employment by the company other than for “cause” (as defined in the agreements) or disability, (ii) termination by the executive for “good reason” (as defined in the agreements), (iii) termination by the executive other than for “good reason,” and (iv) termination of employment because of death or disability. These triggers were designed to ensure the continued availability of the executives following a change of control, and to compensate the executives at appropriate levels if their employment is unfairly or prematurely terminated during the applicable term following a change of control. For more information regarding payment that may be made under our severance arrangements, see our disclosures below under the caption “Potential Payments upon Termination or Change-in-Control Payments.”

Employment Agreements

None of the named executive officers have employment agreements other than the change-of-control agreements described above. As a result, in the event of termination, retirement, death or disability, an officer will only receive compensation or benefits to which he or she would be entitled under the terms of, as applicable, the defined contribution, defined benefit, medical or long-term incentive plans.

Impact of Accounting and Tax Treatments

Accounting Treatment

NuStar Energy’s financial statements include the expense for awards of NuStar Energy L.P. unit options and restricted units to NuStar GP, LLC employees and directors and the expense for awards of NuStar GP Holdings LLC unit options and restricted units to NuStar GP, LLC employees, as we are obligated to pay for all costs of NuStar GP, LLC’s employees working on our behalf in accordance with the Services Agreement described below in Item 13. Certain Relationships and Related Transactions and Director Independence. Under the Services Agreement, 1% of NuStar GP, LLC’s domestic unit compensation expense is charged back to NuStar GP Holdings.

NuStar GP, LLC accounts for awards of NuStar Energy L.P. common units to NuStar GP, LLC’s employees and directors in accordance with Emerging Issues Task Force Issue No. 02-08, “Accounting for Options Granted to Employees in Unrestricted, Publicly Traded Shares of an Unrelated Entity” (EITF 02-08). EITF 02-08 requires a company that grants its employees equity of an unrelated entity to account for such awards as a derivative, whereby a liability for the award is recorded at inception. Subsequent changes in the fair value of the award are included in the determination of net income.

Each month, NuStar GP, LLC determines the fair value of its liability for awards of NuStar Energy L.P. unit options and restricted units. The fair value of unit options is determined using the Black-Scholes model at each reporting date. The fair value of restricted units equals the market price of NuStar Energy L.P. common units at each reporting date. NuStar GP, LLC records compensation expense each reporting period such that the cumulative compensation expense recorded equals the current fair value, considering the percentage of the award that has vested to date. NuStar GP, LLC records compensation expense related to unit options until such options are exercised, and records compensation expense for restricted units until the date of vesting.

NuStar GP Holdings accounts for awards of restricted units and unit options awarded to its directors or employees of NuStar GP, LLC at fair value in accordance with Financial Accounting Standards Board (FASB) Statement No. 123 (revised 2004), “Share-Based Payment” (FAS 123(R)). Under FAS 123(R),value. NuStar GP Holdings estimates the fair value of unit options at the grant date using the Black-Scholes model and the resulting compensation expense is recognized over the vesting period.

NuStar GP Holdings accounts for restricted units awarded to employees of NuStar GP, LLC at fair value in accordance with FASB Statement No. 123 (revised 2004), “Share-Based Payment” (FAS 123R). NuStar GP Holdings estimates the fair value of restricted units equal to the market price at the grant date. The resulting compensation expense is recognized over the vesting period.

For certain awards, the terms of the stock compensation plans provide that employees vest in the award when they retire or will continue to vest in the award after retirement over the nominal vesting period established in the award. For any awards subsequent to January 1, 2006, we recognize compensation expense immediately for awards granted to retirement-eligible employees or over the period from the grant date to the date retirement eligibility is achieved if that date is expected to occur during the nominal vesting period. Employees are typically retirement eligible at age 55.

Tax Treatment

Under Section 162(m) of the Internal Revenue Code, publicly held corporations may not take a tax deduction for compensation in excess of $1 million paid to the CEO or the other four most highly compensated executive officers unless that compensation meets the Internal Revenue Code’s definition of “performance-based” compensation. Section 162(m) allows a deduction for compensation to a specified executive that exceeds $1 million only if it is paid (i) solely upon attainment of one or more performance goals, (ii) pursuant to a qualifying performance-based compensation plan adopted by the Compensation Committee, and (iii) the material terms, including the performance goals, of such plan are approved by the unitholders before payment of the compensation. The Compensation Committee considers deductibility under Section 162(m) with respect to compensation arrangements for executive officers. The Compensation Committee believes that it is in the best interest of NuStar Energy for the Compensation Committee to retain its flexibility and discretion to make compensation awards to foster achievement of performance goals established by the Compensation Committee (which may include performance goals defined in the Internal Revenue Code) and other corporate goals the Compensation Committee deems important to NuStar Energy’s success, such as encouraging employee retention, rewarding achievement of nonquantifiable goals and achieving progress with specific projects. NuStar Energy believes that unit options and performance unit grants qualify as performance-based compensation and are not subject to any deductibility limitations under Section 162(m). Grants of restricted units and other equity-based awards that are not subject to specific quantitative performance measures will likely not qualify as “performance-based” compensation and, in such event, would be subject to 162(m) deduction restrictions.

Compensation-Related Policies

Unit Ownership Guidelines

Our Board, the Compensation Committee and our executives recognize that ownership of NuStar Energy L.P. units is an effective means by which to align the interests of NuStar GP, LLC directors and executives with those of NuStar Energy’s unitholders. We have long emphasized and reinforced the importance of unit ownership among our executives and directors.

During 2006, the Compensation Committee worked with its independent compensation consultant to formalize unit ownership and retention guidelines for directors and NuStar GP, LLC officers to ensure continuation of our successful track record in aligning the interests of NuStar GP, LLC directors and officers with those of NuStar Energy’s unitholders through ownership of NuStar Energy L.P. units. The guidelines were approved by the Compensation Committee and the Board in March 2006. In February 2007, in view of the public offerings of NuStar GP Holdings in 2006, the Compensation Committee amended the guidelines to include ownership of either NuStar GP Holdings LLC units or NuStar Energy L.P. units. An officer or a director’s ownership also includes units subject to vesting.

Non-employee Director Unit Ownership Guidelines

Non-employee directors are expected to acquire and hold during their service as a NuStar GP, LLC boardBoard member NuStar Energy L.P. units and/or NuStar GP Holdings LLC units with an aggregate value of at least $50,000. Directors have five years from their initial election to the Board to meet the target unit ownership guidelines, and they are expected to continuously own sufficient units to meet the guidelines, once attained.

Officer Unit Ownership Guidelines

Unit ownership guidelines for officers of NuStar GP, LLC are as follows:

Officer

  

Value of NuStar Energy L.P. Units and/or NuStar GP

Holdings LLC Units Owned

President

 

  

3.0x Base Salary

Senior Vice Presidents

 

  

2.0x Base Salary

Vice Presidents

 

  

1.0x Base Salary

Our officers are expected to meet the applicable guideline within five years and continuously own sufficient units to meet the guideline, once attained.

Prohibition on Insider Trading and Speculation on NuStar Energy L.P. or NuStar GP Holdings, LLC Units

We have established policies prohibiting our officers, directors and employees from purchasing or selling either NuStar Energy L.P. or NuStar GP Holdings, LLC securities while in possession of material, nonpublic information or otherwise using such information for their personal benefit or in any manner that would violate applicable laws and regulations. Our outside directors, officers and certain other employees are prohibited from trading in either NuStar Energy L.P. or NuStar GP Holdings, LLC securities for the period beginning on the last business day of each calendar quarter through the second business day following our disclosure of our quarterly or annual financial results. In addition, our policies prohibit our officers, directors and employees from speculating in the either NuStar Energy L.P. or NuStar GP Holdings, LLC units, which includes short selling (profiting if the market price of our units decreases), buying or selling publicly traded options (including writing covered calls), hedging or any other type of derivative arrangement that has a similar economic effect. Our directors, officers and certain other employees are also required to receive management consent before they enter into margin loans or other financing arrangements that may lead to the ownership or other rights to their NuStar Energy L.P. or NuStar GP Holdings, LLC securities being transferred to a third party.

EXECUTIVE COMPENSATION

The tables listed below, whichthat appear in the following sections of this report,proxy statement provide information required by the SEC regarding the compensation we paid to or earned by our named executive officers for the yearsyear ended December 31, 2008, December 31, 2007 and December 31, 2006 to our President & CEO, CFO and our other most highly compensated executive officers (our named executive officers or NEOs). Except as noted below, we2009. We have used captions and headingheadings in these tables in accordance with the SEC regulations requiring these disclosures. The footnotes to these tables provide important information to explain the values presented in the tables, and are an important part of our disclosures related to our executive compensation.disclosures.

Summary Compensation Table*

Grants of Plan-Based Awards*

Outstanding Equity Awards

Options Exercises and Stock Vested

Pension Benefits

Nonqualified Deferred Compensation

Payments Under Change of Control Severance Agreements**

Director Compensation

*

We are required to provide narrative disclosure of any material factors necessary to an understanding of the information disclosed in these two tables; we believe that this disclosure is provided in the footnotes to these tables and in the Compensation Disclosure and Analysis above in this item.

**

SEC regulations require disclosure of potential payments to an executive in connection with his or her termination or a change of control of NuStar Energy. We have elected to use the table listed above to disclose certain elements of the required disclosure.

SUMMARY COMPENSATION TABLE

FOR FISCAL YEAR ENDED DECEMBER 31, 20082009

The following table provides a summary of compensation paid for the years ended December 31, 2008,2009, December 31, 20072008 and December 31, 2006,2007 to NuStar GP, LLC’s CEO, CFO and to its three other most highly compensated executive officers. The table shows amounts earned by such persons for services rendered to NuStar GP, LLC in all capacities in which they served.

 

Name and Principal
Position
         Year         Salary ($)         Bonus ($)(1)         Unit
            Awards            
($)(3)
     Option Awards    
($)(4)
 Non-Equity Incentive
    Plan Compensation ($)    
 Change in Pension Value
and Nonqualified
    Deferred Compensation    
Earnings ($)
 All Other
    Compensation    
($)(7)
         Total ($) Year      Salary ($)               Bonus ($)(1)               

Unit Awards  

($)(2)  

 

Option  

Awards ($)(3)  

 

Non-Equity Incentive  

Plan Compensation ($)  

 

Change in Pension Value  

and Nonqualified  

Deferred Compensation  

Earnings ($)(4)  

 

All Other  

Compensation  

($)(5)  

 Total ($)  

Curtis V. Anastasio

President and

CEO

 

 

2008  

 

 

448,400  

 

 

368,000  

 

 

295,135  

 

 

119,121  

 

 

0  

 

 

172,039(5)  

 

 

41,159  

 

 

1,443,854  

 

 

2009     

 

 

466,900                

 

 

284,300                

 

 

832,123  

 

 

0  

 

 

0    

 

 

195,281  

 

 

37,632  

 

 

1,816,236

 

2007  

 

 

428,400  

 

 

393,120  

 

 

168,408  

 

 

14,646  

 

 

0  

 

 

46,806(5)  

 

 

39,568  

 

 

1,090,948  

 

2008     

 

 

448,400                

 

 

368,000                

 

 

739,738  

 

 

0  

 

 

0    

 

 

172,039  

 

 

41,159  

 

 

1,769,336

 

2006  

 

 

385,000  

 

 

320,000  

 

 

165,754  

 

 

250,737  

 

 

0  

 

 

338,020(6)  

 

 

35,481  

 

 

1,495,352  

 

2007     

 

 

428,400                

 

 

393,120                

 

 

620,167  

 

 

413,667  

 

 

0    

 

 

46,806  

 

 

39,568  

 

 

1,941,728

Bradley C. Barron

Senior Vice President,

General Counsel and

Corporate Secretary

 

 

2008  

 

 

249,500  

 

 

132,500  

 

 

68,614  

 

 

51,517  

 

 

0  

 

 

26,079(5)  

 

 

18,931  

 

 

547,141  

 

2007  

 

 

221,167  

 

 

175,500  

 

 

23,222  

 

 

7,903  

 

 

0  

 

 

13,771(5)  

 

 

15,669  

 

 

457,232  

 

2006  

 

 

178,196  

 

 

102,400  

 

 

19,601  

 

 

6,474  

 

 

0  

 

 

24,511(6)  

 

 

18,258  

 

 

349,363  

Steven A. Blank

Senior Vice President,

CFO and Treasurer

 

 

2008  

 

 

324,516  

 

 

165,500  

 

 

160,497  

 

 

152,289  

 

 

0  

 

 

137,330(5)  

 

 

73,227  

 

 

1,013,359  

 

 

2009     

 

 

335,950                

 

 

127,800                

 

 

316,949  

 

 

0  

 

 

0    

 

 

124,551  

 

 

24,266  

 

 

929,516

 

2007  

 

 

311,916  

 

 

238,524  

 

 

93,718  

 

 

18,724  

 

 

0  

 

 

36,731(5)  

 

 

24,150  

 

 

723,763  

 

2008     

 

 

324,516                

 

 

165,500                

 

 

301,406  

 

 

0  

 

 

0    

 

 

137,330  

 

 

73,227  

 

 

1,001,979

 

2006  

 

 

299,900  

 

 

195,172  

 

 

91,387  

 

 

96,103  

 

 

0  

 

 

303,953(6)  

 

 

21,670  

 

 

1,008,725  

 

2007     

 

 

311,916                

 

 

238,524                

 

 

288,565  

 

 

301,250  

 

 

0    

 

 

36,731  

 

 

24,150  

 

 

1,201,136

James R. Bluntzer

Senior Vice President-

Operations

 

 

2008  

 

 

273,840  

 

 

148,000  

 

 

113,281  

 

 

127,192  

 

 

0  

 

 

150,751(5)  

 

 

21,172  

 

 

834,236  

 

2007  

 

 

246,840  

 

 

195,000  

 

 

62,950  

 

 

15,638  

 

 

0  

 

 

135,018(5)  

 

 

20,208  

 

 

675,654  

 

2006  

 

 

231,000  

 

 

154,880  

 

 

57,153  

 

 

48,107  

 

 

0  

 

 

212,397(6)  

 

 

19,683  

 

 

723,100  

Mary F. Morgan

Senior Vice President-

European Operations

 

 

2008  

 

 

290,200  

 

 

648,000(2)  

 

 

193,019  

 

 

0  

 

 

0  

 

 

54,397(5)  

 

 

12,655  

 

 

1,198,291  

 

2007  

 

 

278,970  

 

 

195,000  

 

 

248,169  

 

 

263,640  

 

 

0  

 

 

31,628(5)  

 

 

19,758  

 

 

1,037,165  

 

2006  

 

 

265,971  

 

 

140,032  

 

 

84,827  

 

 

8,223  

 

 

0  

 

 

44,719(6)  

 

 

18,780  

 

 

562,552  

James R. Bluntzer

Senior Vice President -

Operations

 

 

2009     

 

 

301,350                

 

 

115,000                

 

 

286,221  

 

 

0  

 

 

0    

 

 

174,431  

 

 

19,817  

 

 

896,819

 

2008     

 

 

273,840                

 

 

148,000                

 

 

260,195  

 

 

0  

 

 

0    

 

 

150,751  

 

 

21,172  

 

 

853,958

 

2007     

 

 

246,840                

 

 

195,000                

 

 

247,723  

 

 

257,165  

 

 

0    

 

 

135,019  

 

 

20,208  

 

 

1,101,955

Paul W. Brattlof

Senior Vice President-

Supply and Trading

 

 

2009     

 

 

285,392                

 

 

108,600                

 

 

269,663  

 

 

0  

 

 

0    

 

 

39,902  

 

 

19,710  

 

 

723,267

Mary Rose Brown

Senior Vice President-

Administration

 

 

2009     

 

 

301,350                

 

 

115,000                

 

 

286,221  

 

 

0  

 

 

0    

 

 

54,276  

 

 

25,737  

 

 

782,584

Footnotes appear on the following page.

(1)

2009 bonus amounts were paid in February 2010 with respect to 2009 performance. 2008 bonus amounts were paid in February 2009 with respect to 2008 performance. 2007 bonus amounts were paid in January 2008 with respect to 2007 performance. 2006 bonus amounts reported were paid in January 2007 with respect to 2006 performance. Bonuses were determined taking into consideration the individual executive’s targets, the executive’s performance and NuStar Energy’s performance in the applicable year, as described above under “Compensation Disclosure & Analysis- AnnualAnalysis-Annual Incentive Bonus.”

(2)

The amount reported includes a $500,000 retention bonus. Please see “Compensation Disclosure & Analysis- Employment Agreements.”

(3)

The amounts reported represent the dollar amounts recognized by NuStar Energy for financial statement reporting purposes for the fiscal year ended December 31, 2006, December 31, 2007 or December 31, 2008, as applicable. The amounts relate togrant date fair value of grants of restricted NuStar Energy L.P. units, and NuStar Energy L.P. performance units. Beginningunits and, beginning in 2008, the amounts also include dollar amounts recognized with respect to restricted NuStar GP Holdings, LLC units. Please see “Compensation Discussion and Analysis- ImpactAnalysis-Impact of Accounting and Tax Treatment- AccountingTreatment-Accounting Treatment” above in this item for more information.

Since grants to officers who are 55 or over are recognized immediately rather than over the course of the grant, the dollar amounts shown for those officers is much larger in the year of grant (and/or the year in which they turn 55) than the dollar amounts shown for officers who are under 55, even for the same number of restricted units granted. This front-loading of recognition can make comparisons between the officers difficult. For example, in 2008, NuStar Energy immediately recognized the entire FAS 123R value of Ms. Morgan’s 2008 grants, including her grant of restricted NuStar GP Holdings, LLC, or $58,200. Since Mr. Bluntzer is not yet 55 years old, even though he received the same number of restricted NuStar GP Holdings, LLC as Ms. Morgan, NuStar Energy recognized only $1,754 with respect to Mr. Bluntzer’s grant.

(4)(3)

The amounts reported represent the dollar amounts recognized by NuStar Energy for financial statement purposes for the fiscal year ended December 31, 2006, December 31, 2007 or December 31, 2008, as applicable. The amounts relate togrant date fair value of grants of options to purchase NuStar Energy L.P. units and options to purchase NuStar GP Holdings, LLC units. Please see “Compensation Discussion and Analysis- ImpactAnalysis-Impact of Accounting and Tax Treatment- AccountingTreatment-Accounting Treatment” above in this item for more information.

Since grants to officers who are 55 or over are recognized immediately rather than over the course of the grant, the dollar amounts shown for those officers is much larger in the year of grant (and/or the year in which they turn 55) than the dollar amounts shown for officers who are under 55, even for the same number of unit options granted. This front-loading of recognition can make comparisons between the officers difficult. For example, in 2007, NuStar Energy immediately recognized the entire FAS 123R value of the 2007 grant to Ms. Morgan of options to purchase NuStar GP Holdings, LLC units, or $257,165. In 2008, since these options were recognized in the prior year, NuStar Energy recognized nothing with respect to that grant on its financial statements.

Amounts reported with respect to 2008 are the dollar amounts recognized by NuStar Energy for financial statement purposes relating to the grants of options to purchase NuStar GP, Holdings, LLC units. In 2008, the following amounts were recognized with respect to the NuStar Energy unit options for each of the named executive officers. Except in the case of Ms. Morgan, these amounts are negative, and nothing is reflected in the above table with respect to these negative values.

(4)
NameAmount Recognized

Anastasio

($306,240)  

Barron

(3,854)  

Blank

(102,993)  

Bluntzer

(50,530)  

Morgan

12,419  

(5)

For each of the applicable NEOs, the following table identifies the separate amounts attributable to (A) the aggregate change in the actuarial present value of the NEO’s accumulated benefit under NuStar GP, LLC’s defined benefit and actuarial pension plans, including supplemental plans (but excluding tax-qualified defined contribution plans and nonqualified defined contribution plans), and (B) above-market or preferential earnings on compensation that is deferred on a basis that is not tax-qualified.

 

Name    Year    (A)    (B)    TOTAL

Anastasio

    2008      $172,039      $0      $172,039  
    2007      46,806       0       46,806  

Barron

    2008      26,079       0       26,079  
    2007      13,771       0       13,771  
  Name  Year  (A)  (B)  TOTAL
 

Anastasio

  2009    $195,281    $0    $195,281
   2008    172,039    0    172,039
    2007    46,806    0    46,806
 

Blank

  2009    124,551    0    124,551
   2008    137,330    0    137,330
    2007    36,731    0    36,731
 

Bluntzer

  2009    174,431    0    174,431
   2008    150,751    0    150,751
    2007    135,019    0    135,019
 

Brattlof

  2009    39,902    0    39,902
 

Brown

  2009    54,276    0    54,276

Blank

    2008      137,330      0      137,330  
    2007      36,731      0      36,731  

Bluntzer

    2008      150,751      0      150,751  
    2007      135,019      0      135,019  

Morgan

    2008      54,397      0      54,397  
    2007      31,628      0      31,628  

(6)(5)

For each of the NEOs, the following table identifies the separate amounts attributable to (A) the aggregate change in the actuarial present value of the NEO’s accumulated benefit under both Valero Energy’s and NuStar GP, LLC’s defined benefit and actuarial pension plans, including supplemental plans (but excluding tax-qualified defined contribution plans and nonqualified defined contribution plans), and (B) above-market or preferential earnings on compensation that is deferred on a basis that is not tax-qualified. Amounts included in column (A) below include the aggregate change in both the Valero Energy plans (for the period of January 1 through June 30, 2006) and the NuStar GP, LLC plans (for the period of July 1 through December 31, 2006).

Name  (A)  (B)  TOTAL

Anastasio

  $338,020    $0    $338,020  

Barron

  24,511    0    24,511  

Blank

  303,953    0    303,953  

Bluntzer

  212,397    0    212,397  

Morgan

  44,719    0    44,719  

(7)

The amounts reported in this column for 20082009 consist of the following for each officer:

 

Name  Club
Dues
  Company
Contribution
to Thrift Plan
  Company
Contribution
to Excess
Thrift Plan
  Tax
Preparation
  Personal
Liability
Insurance
  Life
Insurance
Premiums
  Payment of
Cash Value of
Split-Dollar
Insurance
Policy
  Cash Payment of
Unused Flex
Dollars (b)
  Executive
Health
Exams (c)
  TOTAL  

Club

Dues      

  

Company

Contribution

to Thrift Plan      

  

 

Company

Contribution      

to Excess

Thrift Plan

  

Tax

Preparation      

  

Personal

Liability

Insurance      

  

Executive

Health

Exams (a)      

  TOTAL        

Anastasio

  7,032    13,800    13,188    797    1,417    3,276    0  1,649    0    41,159    $7,032    $12,650    $15,364    $850    $1,736    $0    $37,632

Barron

  0    10,333    4,637    797    1,417    649    0  0    1,098    18,931  

Blank

  0    12,300    7,232    797    1,417    3,276    47,107 (a)   0    1,098    73,227    0    14,700    5,457    850    1,736    1,523    24,266

Bluntzer

  0    11,750    4,729    0    1,417    3,276    0  0    0    21,172    0    12,510    5,571    0    1,736    0    19,817

Morgan

  0    7,822    55    0    1,417    1,652    0  611    1,098    12,655  

Brattlof

  0    14,952    2,172    850    1,736    0    19,710

Brown

  5,070    6,583    11,498    850    1,736    0    25,737

 (a)

The amount reported is the payment of the cash value of a “split-dollar” life insurance policy paid by NuStar Energy to Mr. Blank in 2008. The policy was carried over by Valero Energy after its acquisition of Ultramar Diamond Shamrock Corporation (UDS) in 2001. Mr. Blank was an employee of UDS. Valero Energy transferred the policy to NuStar Energy after the separation in 2006.

(b)

The amount reported is the unused portion of NuStar Energy-provided dollars for health and welfare benefits.

(c)

The amount reported is the difference between the value of executive health exams made available to NuStar Energy officers and the value of NuStar Energy’s all-employee wellness assessments.

GRANTSOF PLAN-BASED AWARDS

FOR FISCAL YEAR ENDED DECEMBER 31, 20082009

The following table provides further information regarding the grants of plan-based awards to the named executive officers.

 

Name      Grant Date      Date of
approval
by Comp
Committee
  Estimated Future Payouts Under Equity
Incentive Plan Awards
  All Other
Unit
Awards:
Number of
Units (#)
  All Other
Option
Awards:
Number of
Securities
Underlying
Options (#)
  

Exercise or Base Price
of Option Awards

($/Un)

  

Grant Date Fair

Value of Unit and

Unit Option Awards

($)

  Grant Date 

Date of

approval

by Comp

Committee      

 Estimated Future Payouts Under Equity
Incentive Plan Awards
 All Other
Unit
Awards:
Number of
Units (#)      
 All Other
Option
Awards:
Number of
Securities
Underlying
Options (#)      
 

Exercise or Base Price    
of Option Awards

($/Un)

 Grant Date Fair
Value of Unit and
Unit Option Awards  
($)
    Threshold (#)  Target (#)  Maximum (#)        Threshold (#)     Target (#)     

 

 

Maximum (#)    

  
 01/22/2009(1)       01/22/2009       0   6,383   12,766   - -       -       288,895(4)

Anastasio

  01/24/08(1)    01/24/08    0    3,700    7,400    -  -  -  193,473(4) 12/14/2009(2)       10/14/2009       - - - 6,900   -       -       373,773(5)
11/06/08(2)    10/22/08    -  -  -  8,700    -  -  168,780(5)
11/06/08(3)    10/22/08    -  -  -  8,500    -  -  377,485(6)

Barron

  01/24/08(1)    01/24/08    0    1,400    2,800    -  -  -  73,206(4)
11/06/08(2)    10/22/08    -  -  -  2,700    -  -  52,380(5)
11/06/08(3)    10/22/08    -  -  -  2,600    -  -  115,466(6)
 12/14/2009(3)       10/14/2009       - - - 6,500   -       -       169,455(6)
 01/22/2009(1)       01/22/2009       0   2,400   4,800   - -       -       108,624(4)

Blank

  01/24/08(1)    01/24/08    0    1,700    3,400    -  -  -  88,893(4) 12/14/2009(2)       10/14/2009       - - - 2,645   -       -       143,280(5)
11/06/08(2)    10/22/08    -  -  -  3,400    -  -  65,960(5)
11/06/08(3)    10/22/08    -  -  -  3,300    -  -  146,553(6)
 12/14/2009(3)       10/14/2009       - - - 2,495   -       -       65,045(6)
 01/22/2009(1)       01/22/2009       0   2,200   4,400   - -       -       99,572(4)

Bluntzer

  01/24/08(1)    01/24/08    0    1,400    2,800    -  -  -  73,206(4) 12/14/2009(2)       10/14/2009       - - - 2,370   -       -       128,383(5)
11/06/08(2)    10/22/08    -  -  -  3,000    -  -  58,200(5)
11/06/08(3)    10/22/08    -  -  -  2,900    -  -  128,789(6)

Morgan

  01/24/08(1)    01/24/08    0    1,400    2,800    -  -  -  73,206(4)
11/06/08(2)    10/22/08    -  -  -  3,000    -  -  58,200(5)
11/06/08(3)    10/22/08    -  -  -  2,900    -  -  128,789(6)
 12/14/2009(3)       10/14/2009       - - - 2,235   -       -       58,266(6)
 01/22/2009(1)       01/22/2009       0   2,050   4,100   - -       -       92,783(4)

Brattlof

 12/14/2009(2)       10/14/2009       - - - 2,245   -       -       121,612(5)
 12/14/2009(3)       10/14/2009       - - - 2,120   -       -       55,268(6)
 01/22/2009(1)       01/22/2009       0   2,200   4,400   - -       -       99,572(4)

Brown

 12/14/2009(2)       10/14/2009       - - - 2,370   -       -       128,383(5)
 12/14/2009(3)       10/14/2009       - - - 2,235   -       -       58,266(6)

Footnotes:

 (1)

Performance units were awarded by the Board, upon recommendation of the Compensation Committee, on January 24, 2008.22, 2009. Each award is subject to vesting in three annual increments, based upon our TUR during rolling three-year periods that end on December 31 of each year following the date of grant. At the end of each performance period, our TUR is compared to the Peer Group and ranked by quartile. Executives then earn 0%, 50%, 100% or 150% of that portion of the initial grant amount that is vesting, depending upon whether our TUR is in the last, 3rd, 2nd or 1st quartile, respectively, and they earn 200% if we rank highest in the group. Amounts not earned in a given performance period can be carried forward for one additional performance period and up to 100% of the carried amount can still be earned, depending upon the quartile achieved for that subsequent period.earned. For the performance period ended December 31, 2008,2009, our performance ranked in the thirdlast quartile of the group, and 50%none of the eligible units were vested.

 (2)

Restricted units of NuStar GP Holdings, LLC were approved by the Compensation Committee of NuStar GP Holdings at a joint meeting with the Compensation Committee of NuStar GP, LLC on October 22, 2008,14, 2009, and the grant date for these restricted units was set at that time for the date as soon as practicable30 calendar days after the third business day afterclose of NuStar Energy L.P.’s then-impending equity offering. The restricted units vest 1/5 annually over five years beginning on the first anniversary of the grant date.

(3)

Restricted units of NuStar Energy were granted by the Compensation Committee at a joint meeting with the Compensation Committee of NuStar GP Holdings’ quarterly earnings release. Holdings, LLC on October 14, 2009 and the grant date for these restricted units was set at that time for the date 30 calendar days after the close of

NuStar GP Holdings’ earnings release date was October 23, 2008.Energy L.P.’s then-impending equity offering. The restricted units vest 1/5 annually over five years beginning on the first anniversary of the grant date.

(3)

Restricted units of NuStar Energy were granted by the Compensation Committee on October 22, 2008. The restricted units vest 1/5 annually over five years beginning on the first anniversary of the grant date.

 (4)

The grant date fair value for performance units was determined by multiplying the number of performance units that were granted by the NYSE closing unit price of our units on the date of grant, $52.29.

$45.26.

 (5)

The grant date fair value for restricted units was determined by multiplying the number of NuStar GP Holdings, LLC restricted units that were granted by the NYSE closing unit price of NuStar GP Holdings, LLC units on the date of grant, $19.40.

$26.07.

 (6)

The grant date fair value for restricted units was determined by multiplying the number of restricted units that were granted by the NYSE closing unit price of our units on the date of grant, $44.41.

$54.17.

OUTSTANDING EQUITY AWARDS

AT DECEMBER 31, 20082009

The following table provides further information regarding our named executive officers’ unexercised unit options, unvested restricted units and unvested performance units as of December 31, 2008.2009. The value of NuStar Energy restricted units reported below is equal to $41.06,$56.09, the NuStar Energy L.P. closing price on the NYSE on December 31, 2008.2009. The value of the NuStar GP Holdings, LLC restricted units reported below is equal to $17.68,$26.92, the NuStar GP Holdings, LLC closing price on the NYSE on December 31, 2008.2009.

 

  Option Awards  Unit Awards Option Awards Unit Awards
Name  Number of
Securities
Underlying
Unexercised  
Options (#)
Exercisable
  Number of
Securities
Underlying
Unexercised
Options (#)
Unexercisable  
  Equity Incentive Plan
Awards: Number of
Securities Underlying
Unexercised Unearned  
Options (#)
  Option
Exercise  
Price ($)
  Option
Expiration Date  
  Number of Units
That Have Not
Vested (#)
  

Market

Value of

Units That

Have Not

Vested ($)            

  Equity Incentive
Plan Awards:
Number of
Unearned Units
or Other Rights
That Have Not
Vested (#)
  Equity Incentive Plan
Awards: Market or
Payout Value of
Unearned Units or
Other Rights That
Have Not Vested ($)
 Number of
Securities
Underlying
Unexercised
Options (#)
Exercisable
 Number of
Securities
Underlying
Unexercised
Options (#)
Unexercisable  
 Equity Incentive Plan
Awards: Number of
Securities Underlying
Unexercised Unearned
Options (#)  
 Option
Exercise
Price ($)
 Option
Expiration Date  
 Number of Units
That Have Not
Vested (#)
 Market
Value of
Units That
Have Not
Vested ($)
 Equity Incentive
Plan Awards:
Number of
Unearned Units
or Other Rights
That Have Not
Vested (#)
 Equity Incentive Plan  
Awards: Market or
Payout Value of
Unearned Units or
Other Rights That
Have Not Vested ($)
  14,000(1)    0    -  38.22  03/22/2012  -  -  -  - 14,000(1)   0   -       38.22   03/22/2012     -   -         - -
  10,000(2)    0    -  36.30  09/23/2012  -  -  -  - 10,000(2)   0   -       36.30   09/23/2012     -   -         - -
  11,800(3)    0    -  45.35  10/29/2013  -  -  -  - 11,800(3)   0   -       45.35   10/29/2013     -   -         - -

Anastasio

  7,700(4)    1,925    -  56.51  10/28/2014  -  -  -  - 9,625(4)   0   -       56.51   10/28/2014     -   -         - -
  8,070(5)    5,380    -  57.51  10/27/2012  -  -  -  - 10,760(5)   2,690   -       57.51   10/27/2012     -   -         - -
  4,400(6)    6,600    -  55.92  11/02/2013  -  -  -  - 6,600(6)   4,400   -       55.92   11/02/2013     -   -         - -
  0(7)    56,300    -  31.55  11/16/2014  -  -  -  -
  -  -  -  -  -  19,352(9)    794,593    -  -
  -  -  -  -  -  8,700(10)    153,816    -  -
  -  -  -  -  -  9,193(11)    377,465    -  -
  1,280(3)    0    -  45.35  10/29/2013  -  -  -  -
  1,580(4)    395    -  56.51  10/28/2014  -  -  -  -

Barron

  840(6)    1,260    -  55.92  11/02/2013  -  -  -  -
  0(7)    35,000    -  31.55  11/16/2014  -  -  -  - 0(7)   56,300   -       31.55   11/16/2014     -   -         - -
  -  -  -  -  -  5,566(12)    228,540    -  - - - -       -   -     20,602(9)   1,155,566   - -
  -  -  -  -  -  2,700(10)    47,736    -  - - - -       -   -     13,460(10)   362,343   - -
  -  -  -  -  -  2,440(13)    100,186    -  - - - -       -   -     11,739(11)   658,441   - -
  3,333(1)    0    -  38.22  03/22/2012  -  -  -  - 3,333(1)   0   -       38.22   03/22/2012     -   -         - -
  3,333(2)    0    -  36.30  09/23/2012  -  -  -  - 3,333(2)   0   -       36.30   09/23/2012     -   -         - -
  8,700(3)    0    -  45.35  10/29/2013  -  -  -  - 8,700(3)   0   -       45.35   10/29/2013     -   -         - -

Blank

  5,500(4)    1,375    -  56.51  10/28/2014  -  -  -  - 6,875(4)   0   -       56.51   10/28/2014     -   -         - -
  4,335(5)    2,890    -  57.51  10/27/2012  -  -  -  - 5,780(5)   1,445   -       57.51   10/27/2012     -   -         - -
  2,050(6)    3,075    -  55.92  11/02/2013  -  -  -  - 3,075(6)   2,050   -       55.92   11/02/2013     -   -         - -
  0(7)    41,000    -  31.55  11/16/2014  -  -  -  - 0(7)   41,000   -       31.55   11/16/2014     -   -         - -
  -  -  -  -  -  8,676(14)    356,237    -  - - - -       -   -     8,565(12)   480,411   - -
  -  -  -  -  -  3,400(10)    60,112    -  - - - -       -   -     5,215(13)   140,388   - -
  -  -  -  -  -  4,390(15)    180,253         - - -       -   -     4,907(14)   275,234   - -
  4,500(1)    0    -  38.22  03/22/2012  -  -  -  - 4,500(1)   0   -       38.22   03/22/2012     -   -         - -
  2,675(3)    0    -  45.35  10/29/2013  -  -  -  - 2,675(3)   0   -       45.35   10/29/2013     -   -         - -
  1,980(4)    495    -  56.51  10/28/2014  -  -  -  - 2,475(4)   0   -       56.51   10/28/2014     -   -         - -

Bluntzer

  3,240(5)    2,160    -  57.51  10/27/2012  -  -  -  - 4,320(5)   1,080   -       57.51   10/27/2012     -   -         - -
  1,620(6)    2,430    -  55.92  11/02/2013  -  -  -  - 2,430(6)   1,620   -       55.92   11/02/2013     -   -         - -
  0(7)    35,000    -  31.55  11/16/2014  -  -  -  - 0(7)   35,000   -       31.55   11/16/2014     -   -         - -
 - - -       -   -     7,472(15)   419,104   - -
 - - -       -   -     4,635(16)   124,774   - -
 - - -       -   -     4,216(17)   236,475   - -

   -  -          -          -  -  7,152(16)    293,661            -                  -        
   -  -  -  -  -  3,000(10)    53,040    -  -
   -  -  -  -  -  3,480(17)    142,889    -  -
   2,640(8)    1,760    -  60.25    07/01/2012    -  -  -  -
   2,430(5)    1,620    -  57.51    10/27/2012    -  -  -  -

Morgan

  1,150(6)    1,725    -  55.92    11/02/2013    -  -  -  -
   0(7)    35,000    -  31.55    11/16/2014    -  -  -  -
   -  -  -  -  -  7,294(18)    299,492    -  -
   -  -  -  -  -  3,000(10)    53,040    -  -
   -  -  -  -  -  2,896(19)    118,910    -  -
  680(8)   1,020   -       69.15   04/30/2014     -   -         - -
  0(7)   35,000   -       31.55   11/16/2014     -   -         - -

Brattlof

 - - -       -   -     6,885(18)   386,180   - -
  - - -       -   -     4,360(19)   117,371   - -
  - - -       -   -     3,578(20)   200,690   - -
  680(8)   1,020   -       69.15   04/30/2014     -   -         - -
  0(7)   35,000   -       31.55   11/16/2014     -   -         - -

Brown

 - - -       -   -     7,090(21)   397,678   - -
  - - -       -   -     4,635(22)   124,774   - -
  - - -       -   -     3,728(23)   209,104   - -

Footnotes on following page.

Footnotes:

 (1)

Options granted March 22, 2002 vested in 1/3 increments over three years, beginning on the first anniversary of the date of grant.

 (2)

Options granted September 23, 2002 vested in 1/3 increments over three years, beginning on the first anniversary of the date of grant.

 (3)

Options granted October 29, 2003 vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.

 (4)

Options granted on October 28, 2004 vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.

 (5)

Options granted on October 27, 2005 vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.

 (6)

Options granted on November 2, 2006 vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.

 (7)

Options of NuStar GP Holdings granted November 16, 2007 vest in 1/3 increments over three years, beginning on the third anniversary of the date of grant.

 (8)

Options granted July 1, 2005April 30, 2007 vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.

 (9)

Mr. Anastasio’s restricted NuStar Energy L.P. units consist of: 770 restricted units granted October 28, 2004; 1,800900 restricted units granted October 27, 2005; 2,5141,676 restricted units granted November 2, 2006; 5,7684,326 restricted units granted November 16, 2007; and 8,5006,800 restricted units granted November 6, 2008.2008; and 6,900 restricted units granted December 14, 2009. All of Mr. Anastasio’s restricted units vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.

 (10)

TheMr. Anastasio’s restricted NuStar GP Holdings, LLC units wereconsist of: 6,960 restricted units granted November 6, 2008 whichand 6,500 restricted units granted December 14, 2009. All of Mr. Anastasio’s restricted units vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.

 (11)

Mr. Anastasio’s unvested NuStar Energy L.P. performance units were granted January 26, 2006, January 25, 2007, and January 24, 2008 and January 22, 2009 and vest annually in 1/3 increments over three years beginning on the first anniversary of their grant date. The performance units are payable in NuStar Energy L.P.’s units. Upon vesting, the performance units are converted into a number of NuStar Energy L.P. units based on NuStar Energy’s TUR during rolling three-year periods that end of December 31 of each year following the date of grant. At the end of each performance period, NuStar Energy’s TUR is compared to the Peer Group and ranked by quartile. Holders of the performance units then earn 0%, 50%, 100% or 150% of that portion of the initial grant that is vesting, depending upon whether NuStar Energy’s TUR is in the last, third, second or first quartile, respectively; holders earn 200% if NuStar Energy is the highest ranking entity in the Peer Group. For the period ended December 31, 2006, NuStar Energy’s TUR was in the second quartile of it and the Peer Group, which resulted in a 100% vest for participants. Mr. Anastasio received a total of 947 units for the 2006 performance period. For the period ended December 31, 2007, NuStar Energy’s TUR was in the fourth quartile of it and the Peer Group, which resulted in no vesting for participants. Mr. Anastasio received no vested performance units for the 2007 period. For the period ended December 31, 2008, NuStar’s TUR was in the third quartile of it and the Peer Group, which resulted in a 50% vest for participants. Mr. Anastasio received a total of 2,763 units for the 2008 performance period.

For the period ended December 31, 2009, NuStar’s TUR was in the last quartile of it and the Peer Group, which resulted in no vesting for participants.
 (12)

Mr. Barron’s restricted NuStar Energy L.P. units consist of: 86 restricted units granted October 28, 2004; 480 restricted units granted November 2, 2006; 2,400 restricted units granted November 16, 2007; and 2,600 restricted units granted November 6, 2008. All of Mr. Barron’s restricted units vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.

(13)

Mr. Barron’s unvested NuStar Energy L.P. performance units were granted and vest in accordance with Footnote (11) above. For the 2006 period, Mr. Barron received a total of 180 units. For the 2007 period, Mr. Barron received no vested performance units. For the 2008 period, Mr. Barron received a total of 639 units.

(14)

Mr. Blank’s restricted NuStar Energy L.P. units consist of: 550 restricted units granted October 28, 2004; 968484 restricted units granted October 27, 2005; 1,170780 restricted units granted November 2, 2006; 2,6882,016 restricted units granted November 16, 2007; and 3,3002,640 restricted units granted November 6, 2008.2008; and 2,645 restricted units granted December 14, 2009. All of Mr. Blank’s restricted units vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.

 (15)(13)Mr. Blank’s restricted NuStar GP Holdings, LLC units consist of: 2,720 restricted units granted November 6, 2008 and 2,495 restricted units granted December 14, 2009. All of Mr. Blank’s restricted units vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.
(14)

Mr. Blank’s unvested NuStar Energy L.P. performance units were granted January 26, 2006, January 25, 2007, January 24, 2008 and January 22, 2009 and vest in accordance with the description in Footnote (11) above. For the 2006 period, Mr. Blank received a total of 510 units.

For the 2007 period, Mr. Blank received no vested performance units. For the 2008 period, Mr. Blank received a total of 1,350 units. For the 2009 period, Mr. Blank received no vested performance units.

 (16)(15)

Mr. Bluntzer’s restricted NuStar Energy L.P. units consist of: 198 restricted units granted October 28, 2004; 724362 restricted units granted October 27, 2005; 930620 restricted units granted November 2, 2006; 2,4001,800 restricted units granted November 16, 2007; and 2,9002,320 restricted units granted November 6, 2008.2008 and 2,370 restricted units granted December 14, 2009. All of Mr. Bluntzer’s restricted units vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.

(16)Mr. Bluntzer’s restricted NuStar GP Holdings, LLC units consist of: 2,400 restricted units granted November 6, 2008 and 2,235 restricted units granted December 14, 2009. All of Mr. Bluntzer’s restricted units vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.
 (17)

Mr. Bluntzer’s unvested NuStar Energy L.P. performance units were granted January 26, 2006, January 25, 2007, January 24, 2008 and January 22, 2009 and vest in accordance with Footnote (11) above. For the 2006 period ended December 31, 2006, Mr. Bluntzer received a total of 380 units. For the 2007 period, Mr. Bluntzer received no vested performance units. For the 2008 period, Mr. Bluntzer received a total of 1,054 units.

For the 2009 period, Mr. Bluntzer received no vested performance units.
 (18)

Ms. Morgan’sMr. Brattlof’s restricted NuStar Energy L.P. units consist of: 800600 restricted units granted July 1, 2005; 540 restricted units granted October 27, 2005; 654 restricted units granted November 2, 2006; 2,400April 30, 2007; 1,800 restricted units granted November 16, 2007; and 2,9002,240 restricted units granted November 6, 2008.2008; and 2,245 restricted units granted December 14, 2009. All of Ms. Morgan’sMr. Brattlof’s restricted units vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.

 (19)

Ms. Morgan’sMr. Brattlof’s restricted NuStar GP Holdings, LLC units consist of: 2,240 restricted units granted November 6, 2008 and 2,120 restricted units granted December 14, 2009. All of Mr. Brattlof’s restricted units vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.

(20)Mr. Brattlof’s unvested NuStar Energy L.P. performance units were granted April 30, 2007, January 24, 2008 and January 22, 2009 and vest in accordance with Footnote (11) above. For the 20062009 period, Ms. Morgan received a total of 284 units. For the 2007 period, Ms. MorganMr. Brattlof received no vested performance units.
(21)Ms. Brown’s restricted NuStar Energy L.P. units consist of: 600 restricted units granted April 30, 2007; 1,800 restricted units granted November 16, 2007; 2,320 restricted units granted November 6, 2008; and 2,370 restricted units granted December 14, 2009. All of Ms. Brown’s restricted units vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.
(22)Ms. Brown’s restricted NuStar GP Holdings, LLC units consist of: 2,400 restricted units granted November 6, 2008 and 2,235 restricted units granted December 14, 2009. All of Ms. Brown’s restricted units vest in 1/5 increments over five years, beginning on the first anniversary of the date of grant.
(23)Mr. Brown’s unvested NuStar Energy L.P. performance units were granted April 30, 2007, January 24, 2008 and January 22, 2009 and vest in accordance with Footnote (11) above. For the 20082009 period, Ms. MorganBrown received a total of 827no vested performance units.

OPTION EXERCISESAND UNITS VESTED

IN YEAR ENDED DECEMBER 31, 20082009

The following table provides further information regarding option exercises by our named executive officers, and the vesting of restricted units and performance units held by our named executive officers, during 2008.2009.

 

  Option Awards(1)  Unit Awards(2) Option Awards(1) Unit Awards
Name  Number of Units
Acquired on Exercise
(#)
  Value Realized on
Exercise ($)
  Number of Units
Acquired on Vesting
(#)
  Value Realized on
Vesting ($)(8)
 Number of Units
Acquired on Exercise
(#)
 Value Realized on
Exercise ($)
 Number of Units
Acquired on Vesting
(#)
 Value Realized on
Vesting ($)(7)

Anastasio

  -  -  4,020(3)  174,042 - - 10,153(2) 469,220

Barron

  -  -     912(4)    39,453

Blank

  -  -  2,148(5)    92,933 - -   4,786(3) 224,864

Bluntzer

  -  -  1,580(6)    68,371 - -   3,704(4) 171,807

Morgan

  -  -  1,488(7)    65,793

Brattlof

 - -   2,396(5) 107,115

Brown

 - -   2,456(6) 109,146

Footnotes:

 (1)

None of the named executive officers exercised options in 2008.

2009.
 (2)

While these columns would typically include both performanceMr. Anastasio’s NuStar Energy L.P. units vested in 2009 as follows: 2,763 units on January 22, 2009; 900 units on October 27, 2009; 770 units on October 28, 2009; 838 units on November 2, 2009; 1,700 units on November 6, 2009 and restricted unit vestings in 2008, there were no performance unit vestings in 2008.

1,442 units on November 16, 2009. Mr. Anastasio vested for 1,740 NuStar GP Holdings, LLC units on November 6, 2009.
 (3)

Mr. Anastasio’sBlank’s NuStar Energy L.P. units vested in 20082009 as follows: 9001,350 units on January 22, 2009; 484 units on October 27, 2008; 7702009; 550 units on October 28, 2008, 70 units on October 29, 2008; 8382009; 390 units on November 2, 2008;2009; 660 units on November 6, 2009; and 1,442672 units on November 16, 2008.

2009. Mr. Blank vested for 680 NuStar GP Holdings, LLC units on November 6, 2009.
 (4)

Mr. Barron’sBluntzer’s NuStar Energy L.P. units vested in 20082009 as follows: 861,054 units on January 22, 2009; 362 units on October 27, 2009; 198 units on October 28, 2008; 66 units on October 29, 2008; 1602009; 310 units on November 2, 2008;2009; 580 units on November 6, 2009; and 600 units on November 16, 2008.

2009. Mr. Bluntzer vested for 600 NuStar GP Holdings, LLC units on November 6, 2009.
 (5)

Mr. Blank’sBrattlof’s NuStar Energy L.P. units vested in 20082009 as follows: 484476 units on October 27, 2008; 550January 22, 2009; 200 units on October 28, 2008; 52 units on October 29, 2008; 390April 30, 2009; 560 units on November 2, 2008;6, 2009; and 672600 units on November 16, 2008.

2009. Mr. Brattlof vested for 560 NuStar GP Holdings, LLC units on November 6, 2009.
 (6)

Mr. Bluntzer’sMs. Brown’s units vested in 20082009 as follows: 362476 units on October 27, 2008; 198January 22, 2009; 200 units on October 28, 2008; 110 units on October 29, 2008; 310April 30, 2009; 580 units on November 2, 2008;6, 2009; and 600 units on November 16, 2008.

2009. Ms. Brown vested for 600 NuStar GP Holdings, LLC units on November 6, 2009.
 (7)

Ms. Morgan’s units vested in 2008 as follows: 400 units on July 1, 2008; 270 units on October 27, 2008; 218 units on November 2, 2008; and 600 units on November 16, 2008.

(8)

The value realized on vesting was calculated by multiplying the closing price of NuStar Energy L.P. units on the NYSE on the date of vesting by the number of NuStar Energy L.P. units vested.vested or the closing price of NuStar GP Holdings, LLC units on the NYSE on the date of vesting by the number of NuStar GP Holdings, LLC units vested, as applicable. The closing prices of the applicable dates are as follows:

 

Vesting Date

  NS Closing Price ($)

July 1, 2008January 22, 2009

  47.4045.26

April 30, 2009

50.39

October 27, 20082009

  42.0053.59

October 28, 20082009

  43.33

October 29, 2008

44.0953.35

November 2, 2008 (close 10/31)2009

  46.1453.60

November 6, 2009

54.11

November 16, 2008 (close 11/14)2009

  42.3953.20
NSH Closing Price ($)

November 6, 2009

23.70

POST-EMPLOYMENT COMPENSATION

PENSION BENEFITS

FOR YEAR ENDED DECEMBER 31, 20082009

The following table provides information regarding the accumulated benefits of our named executive officer under NuStar GP, LLC’s pension plans during the year ended December 31, 2008.2009.

 

Name  Plan Name  Number of Years
Credited Service
  Present Value of
Accumulated
Benefit($)(1)
  Payments During Last
Fiscal Year
  Plan Name  

Number of Years

Credited Service

  

Present Value of
Accumulated

Benefit($)(1)

  Payments During Last
Fiscal Year

Anastasio

  NuStar GP, LLC
Pension Plan
  2.5    45,288    0  NuStar GP, LLC Pension Plan  3.5    80,323    0
NuStar GP, LLC
Excess Pension Plan
  -  98,061    0 NuStar GP, LLC Excess Pension Plan  -  173,991    0
NuStar GP, LLC
Supplemental Executive Retirement   Plan
  7.0    335,055    0

Barron

  NuStar GP, LLC
Pension Plan
  2.5    23,541    0
NuStar GP, LLC
Excess Pension Plan
  8.0    34,338    0
NuStar GP, LLC
Supplemental Executive Retirement Plan
  -  -  0
  NuStar GP, LLC Supplemental Executive Retirement Plan  8.0    419,371    0

Blank

  NuStar GP, LLC
Pension Plan
  2.5    50,216    0  NuStar GP, LLC Pension Plan  3.5    87,858    0
Excess Pension Plan  -  61,679    0 NuStar GP, LLC Excess Pension Plan  -  98,318    0
Supplemental Executive Retirement Plan  7.0    245,314    0
  NuStar GP, LLC Supplemental Executive Retirement Plan  8.0    295,584    0

Bluntzer

  NuStar GP, LLC
Pension Plan
  2.5    49,929    0  NuStar GP, LLC Pension Plan  3.5    87,421    0
Excess Pension Plan  32.7    517,730    0 Excess Pension Plan  33.7    654,669    0
Supplemental Executive Retirement Plan  -  -  0

Morgan

  NuStar GP, LLC
Pension Plan
  2.5    59,311    0
Excess Pension Plan  3.5    64,203    0
Supplemental Executive Retirement Plan  -  -  0
  Supplemental Executive Retirement Plan  -  -  0

Brattlof

  NuStar GP, LLC Pension Plan  2.8    46,810    0
Excess Pension Plan  2.8    34,083    0
  Supplemental Executive Retirement Plan  -  -  0

Brown

  NuStar GP, LLC Pension Plan  2.7    61,538    0
Excess Pension Plan  2.7    54,526    0
  Supplemental Executive Retirement Plan  -  -  0

Footnotes:

 (1)

The present values stated above were calculated using the same interest rate and mortality table that we use for valuations under FASB Statement No. 87 for financial reporting purpose. The present values as of December 31, 20082009 were determined using: (a) a 7.13%6.16% discount rate, and (b) the plans’ earliest unreduced retirement age (i.e., age 62). The present values reflect postretirement mortality rates based on the RP2000 Combined Healthy Mortality Table Projected by Scale AA to 2015. No decrements were included for preretirement termination, mortality or disability. Where applicable, lump sums were determined based on a 6.38%6.16% interest rate and the mortality table prescribed by the Internal Revenue Service in Revenue Ruling 2007-67 and updated by IRS Notice 2008-85 for 2008 distributions.

distributions in the years 2009-2013.

We maintain a noncontributory defined benefit pension plan in which most of our employees are eligible to participate and under which contributions by individual participants are neither required nor permitted. We also maintain a noncontributory, non-qualified excess pension plan and a non-qualified supplemental executive retirement plan, or SERP, which provide supplemental pension benefits to certain highly compensated employees. The excess pension plan and the SERP provide eligible employees with additional retirement savings opportunities that cannot be achieved with tax-qualified plans due to Internal Revenue Code of 1986, as amended (the Code)the Code’s limits on (1) annual compensation that can be taken into account under qualified plans or (2) annual benefits that can be provided under qualified plans. Employees who are eligible for the excess pension plans and the SERP may participate in one or the other, but not both plans.

NuStar GP, LLC Pension Plan

The NuStar GP, LLC Pension Plan (the Pension Plan) is a traditional defined benefit pension plan established as of July 1, 2006 and designed to provide retirement benefits to our eligible employees based upon a specific formula. The formula used to calculate a pension benefit under the plan takes into consideration final average salary and total years of credited service. Certain participants who were participants in the Valero Energy Pension Plan prior to becoming eligible for participation in the Pension Plan received credit for their service recognized under the Valero Energy Pension Plan for purposes of vesting and eligibility under this plan.

Under an agreement between the companies, Valero Energy will pay pension benefits to eligible NuStar GP, LLC employees for their years of service with Valero Energy under the Valero Energy pension plan, and the employee’s highest annual salary will be determined with regard to service with NuStar GP, LLC after July 1, 2006 until the individual commences a benefit under the Valero Energy pension plan or terminates employment with NuStar GP, LLC. For more information about the Valero Energy Pension Plan, please see Valero Energy’s annual report on Form 10-K for the year ended December 31, 2008 and its 2009 annual proxy statement. The Pension Plan is intended to be a qualified plan under, and subject to, relevant provisions of the Code and the Employee Retirement Income Security Act of 1974, as amended (ERISA).

The Pension Plan (supplemented, as necessary, by the excess pension plan or the SERP described below) provides a monthly pension at normal retirement equal to 1.6% of the eligible employee’s average monthly compensation (based upon the eligible employee’s earnings during the three consecutive calendar years during the last ten years of the eligible employee’s credited service, including service with our former parent, Valero Energy, affording the highest such average) times the eligible employee’s years of credited service. Pension benefits are not subject to any deduction for social security or other offset amounts.

Eligible employees are NuStar GP, LLC employees, except for those employees who are nonresident aliens, who are U.S. citizens but being paid by a foreign affiliated employer (as defined in the plan), who are covered by a collective bargaining agreement (unless it expressly provides for the benefits provided under the plan), or who are not yet participating.

NuStar GP, LLC Excess Pension Plan

The NuStar GP, LLC Excess Pension Plan was established effective as of July 1, 2006 for the purpose of providing benefits to eligible employees of NuStar GP, LLC whose pension benefits under the NuStar GP, LLC Pension Plan and the Valero Energy Pension Plan, where applicable, are subject to limitations under the Code. The Excess Pension Plan is an excess benefit plan as contemplated under ERISA for those benefits provided in excess of Section 415 of the Code. Benefits provided as a result of other statutory limitations are limited to a select group of management or highly compensated employees. The Excess Pension Plan is not intended to constitute either a qualified plan under the Code or a funded plan subject to ERISA. For employees of NuStar GP, LLC who were eligible to receive a benefit under the Valero Energy Excess Pension Plan (the Predecessor Excess Pension Plan) as of July 1, 2006, the Excess Pension Plan assumed the liabilities of the Predecessor Excess Pension Plan and will provide a single, nonqualified defined benefit to eligible employees for their pre-July 1, 2006 benefit accruals under the Predecessor Excess Pension Plan and their post-July 1, 2006 benefit accruals under this Excess Pension Plan.

An eligible employee’s monthly pension under the Excess Pension Plan will be equal to (i) 1.6% of the employee’s average monthly compensation multiplied by the employee’s years of serviceless (ii) the employee’s Pension Plan benefit. Mr. Barron,Bluntzer, Mr. BluntzerBrattlof and Ms. MorganBrown participate in the Excess Pension Plan.

NuStar GP, LLC Supplemental Executive Retirement Plan

The SERP was established effective as of July 1, 2006 for the purpose of providing certain highly compensated, management personnel of NuStar GP, LLC and its subsidiaries a supplement to the retirement benefit they may otherwise receive under the Pension Plan and the Valero Energy Pension Plan, where applicable. The SERP is not intended to constitute either a qualified plan under the Code or a funded plan subject to ERISA. For employees of NuStar GP, LLC who were eligible to receive a benefit under the Valero Energy Supplemental Executive Retirement Plan (the Prior SERP) as of July 1, 2006, the SERP assumed the liabilities of the Prior SERP and shall provide a single, nonqualified defined benefit to eligible employees for their pre-July 1, 2006 benefit accruals under the Prior SERP and their post-July 1, 2006 benefit accruals under this SERP.

An eligible employee’s monthly pension under the SERP will be equal to:

 (i)

1.6% of the employee’s average monthly compensation multiplied by the employee’s years of service;plus

 (ii)

0.35% of the product of the employee’s years of service and the amount that the employee’s average monthly compensation exceeds the lesser of:

 a.

1.25 multiplied by the employee’s monthly covered compensation and

 b.

the monthly FICA amount;minus

 (iii)

the employee’s Pension Plan benefit.

Mr. Anastasio and Mr. Blank participate in the SERP.

NONQUALIFIED DEFERRED COMPENSATION

FOR YEAR ENDED DECEMBER 31, 20082009

The following table provides additional information regarding contributions by NuStar GP, LLC and each of our named executive officers under our non-qualified defined contribution and other deferred compensation plans during the year ended December 31, 2008.2009. The table also presents each named executive officer’s withdrawals, earnings and year-end balances in such plans. Please see the descriptions of our Excess Thrift Plan and the Frozen Nonqualified 401(k) Plan above in “Compensation Discussion and Analysis- Post-Employment Benefits.”

 

Name  Executive
Contributions in 
2008 ($)(1)
  Registrant
Contributions in 
2008 ($)(2)
  Aggregate
Earnings in 2008 
($)(3)
  Aggregate
Withdrawals/ 
Distributions
($)(4)
  Aggregate
Balance at
December 31, 
2008 ($)(5)
  Executive
Contributions
in 2009 ($)(1)
  Registrant
Contributions in
2009 ($)(2)
  Aggregate
Earnings in 2009
($)(3)
  Aggregate
Withdrawals/
Distributions
($)(4)
  Aggregate
Balance at
December 31,
2009 ($)(5)

Anastasio

  0    13,188    0    0    290,949    0    15,364    63,907    0    381,892

Barron

  0    4,637    0    0    4,654  

Blank

  0    7,232    0    0    793,611    0    5,457    180,874    0    1,010,265

Bluntzer

  0    4,729    0    0    6,295    0    5,571    2,847    0    15,211

Morgan

  0    55    0    0    3,890  

Brattlof

  0    2,172    1,165    0    6,527

Brown

  0    11,498    686    0    12,258

Footnotes:

 

 (1)

The executives made no contributions to ourthese plans in 2008.

2009.
 (2)

Amounts reported represent our contributions to our Excess Thrift Plan. All of the amounts included in this column are included within the amounts reported as “All Other Compensation” for 20082009 in the Summary Compensation Table.

 (3)

Amounts include the earnings (excluding dividends, if any), if any, of the executives’ respective account in (as applicable) our Excess Thrift Plan and our Frozen Nonqualified 401(k) Plan. In each case, the executives’ respective Excess Thrift Plan and, if applicable, Frozen Nonqualified 401(k) Plan had negative aggregate earnings in 2008, as set forth below.

NameAggregate Earnings

Anastasio

-82,183

Barron

-247

Blank

-465,282

Bluntzer

-472

Morgan

-1,111

 (4)

The executives made no withdrawals from and received no distributions under our plans in 2008.

2009.
 (5)

Amounts include the aggregate balance, if any, of the executives’ respective account in (as applicable) our Excess Thrift Plan and our Frozen Nonqualified 401(k) Plan.

POTENTIAL PAYMENTS UPON TERMINATION OR CHANGE OF CONTROL

Each of our named executive officers has entered into a Change of Control Severance Agreement with NuStar Energy and NuStar GP, LLC. These agreements are intendedseek to assure the continued availability of these executives in the event of a “change of control” (described below). The of NuStar. When determining the amounts and benefits payable under the agreements, have three-year terms, which are automatically extended for one year upon each anniversary unless a notice of nonrenewalthe Compensation Committee sought to secure compensation that is competitive in our market in order to recruit and retain executive officer talent. Consideration was given to the executive. principal economic terms found in written employment and change of control agreements of other publicly traded companies.

When a change of control occurs, the agreement becomes operative for a fixed three-year period. The agreements provide generally that the executive’s terms and conditions of employment (including position, location, compensation and benefits) will not be adversely changed during the three-year period after a change of control. In addition, outstanding unit options held by the executive will automatically vest, restrictions applicable to outstanding restricted units held by the executive will lapse, and all unvested performance units held by the executive will fully vest and become payable at 200% of target. In addition to the payments and benefits accruing to theThe executives under the various circumstances described in the agreements, the executives are also entitled to receive a payment in an amount sufficient to make the executive whole for any excise tax on excess parachute payments imposed under Section 4999 of the Internal Revenue Code of 1986, as amended, if the amount of the payment exceeds the safe harbor limit by at least 110%.Code. Each agreement subjects the executive to obligations of confidentiality, both during the term and after termination, for secret and confidential information relating to NuStar Energy, NuStar GP, LLC and their affiliates (as defined in the agreement) that the executive acquired during his or her employment.

For purposes of these agreements, a “change of control” means any of the following (subject to additional particulars as stated in the agreements):

 

the acquisition by an individual, entity or group of beneficial ownership of 40% of NuStar GP Holdings’ voting interests;

the failure of NuStar GP Holdings to control NuStar GP, LLC, NuStar Energy’s general partner, Riverwalk Logistics, L.P., or all of the general partner interests of NuStar Energy;

Riverwalk Logistics, L.P. ceases to be NuStar Energy’s general partner or Riverwalk Logistics, L.P. is no longer controlled by either NuStar GP, LLC or one of its affiliates;

the acquisition of more than 50% of all voting interests of NuStar Energy then outstanding;

certain consolidations or mergers of NuStar GP Holdings;

certain consolidations or mergers of NuStar Energy;

sale of all or substantially all of the assets of NuStar GP Holdings to anyone other than its affiliates;

sale of all or substantially all of the assets of NuStar Energy to anyone other than its affiliates; or

change in the composition of the NuStar GP Holdings board of directors so that fewer than a majority of those directors are “incumbent directors” as defined in the agreement.

In the agreements, “cause” is defined to mean, generally, the willful and continued failure of the executive to perform substantially the executive’s duties, or the willful engaging by the executive in illegal or gross misconduct that is materially and demonstrably injurious to the company. “Good reason” is defined to mean, generally:

 

a diminution in the executive’s position, authority, duties and responsibilities,

failure of the successor of NuStar Energy or NuStar GP, LLC (or of their respective successors) to comply with the provisions ofassume and perform under the agreement, and

relocation of the executive or increased travel requirements,requirements.

SEC regulations require us to disclose potential payments to an executive in connection with his or her termination or a change of control of NuStar. We have elected to use the following table to make the required disclosures. Except as noted, values assumes that a change of control occurred on December 31, 2009, and

termination of that the executive’s employment other than as permitted bywas terminated on that date.

Under the agreement.

The following table discloses the amounts payable to our named executive officers under the different circumstances relating to a change of control; however,control agreements, if the executive’san executive officer’s employment is terminated for “cause,” then the executiveofficer will not receive any benefits or compensation other than any accrued salary or vacation pay that remained unpaid through the date of termination, and, therefore, there is no presentation of termination for “cause” in the table below. Except as noted below, the table assumes that a change of control occurred on December 31, 2008, and that the executive’s employment was terminated on that date.

PAYMENTS UNDER CHANGE OF CONTROL SEVERANCE AGREEMENTS

 

Executive Benefits and
Payments
Termination of
Employment by the
Company Other Than
for “Cause” or
Disability, or by the
Executive for “Good
Reason” (2)
Termination of
Employment
because of Death or
Disability (3)
Termination by the
Executive Other
Than for “Good
Reason” (4)
Continued
Employment
Following
Change of
Control (5)

Salary (1)

Anastasio

Barron

Blank

Bluntzer

Morgan

$1,380,000 

530,000 

662,000 

593,200 

593,200 

$0 

$0 

(5)

Bonus (1)

Anastasio

Barron

Blank

Bluntzer

Morgan

$1,179,360 

351,000 

477,048 

390,000 

390,000 

$393,120 

175,500 

238,524 

195,000 

195,000 

$393,120 

175,500 

238,524 

195,000 

195,000 

(5)

Pension, Excess Pension, and   SERP Benefits

Anastasio

Barron

Blank

Bluntzer

Morgan

$552,014 

121,158 

214,604 

437,290 

205,831 

$0 

$0 

(5)

Contributions under Defined   Contribution Plans

Anastasio

Barron

Blank

Bluntzer

Morgan

$153,562 

52,860 

68,343 

58,992 

58,992 

$0 

$0 

(5)

Health and Welfare Plan Benefits

Anastasio

Barron

Blank

Bluntzer

Morgan

(6)

$76,164 

28,311 

47,333 

32,364 

39,049 

$0 

$0 

(5)

Executive Benefits and Payments    

Termination of

Employment by the
Company Other Than for
“Cause” or Disability, or by
the Executive for “Good
Reason” (2)

  

Termination of

Employment because of
Death or Disability (3)

  

Termination by the
Executive Other Than

for “Good Reason” (4)

  

Continued

Employment

Following Change of
Control (5)

Salary (1)

            

Anastasio

  $1,421,400    $0    $0    $0

Blank

  681,800    0    0    0

Bluntzer

  611,000    0    0    0

Brattlof

  579,200    0    0    0

Brown

  611,000    0    0    0
             
             

Bonus (1)

            

Anastasio

  $1,179,360    $393,120    $393,120    $0

Blank

  477,048    238,524    238,524    0

Bluntzer

  390,000    195,000    195,000    0

Brattlof

  390,000    195,000    195,000    0

Brown

  390,000    195,000    195,000    0
             
             
Pension, Excess Pension, and SERP Benefits            

Anastasio

  $589,534    $0    $0    $0

Blank

  225,641    0    0    0

Bluntzer

  321,781    0    0    0

Brattlof

  117,421    0    0    0

Brown

  160,283    0    0    0
             
             
Contributions under Defined Contribution Plans            

Anastasio

  $156,046    $0    $0    $0

Blank

  69,531    0    0    0

Bluntzer

  60,060    0    0    0

Brattlof

  58,152    0    0    0

Brown

  60,060    0    0    0
             
             
Health and Welfare Plan Benefits (6)            

Anastasio

  $77,163    $0    $0    $0

Blank

  47,702    0    0    0

Bluntzer

  33,668    0    0    0

Brattlof

  43,426    0    0    0

Brown

  30,114    0    0    0
             
             
Accelerated Vesting of Unit Options (7)            

Anastasio

  $748    $748    $748    $748

Blank

  349    349    349    349

Bluntzer

  275    275    275    275

Brattlof

  0    0    0    0

Brown

  0    0    0    0
             
Accelerated Vesting of Restricted Units (8)            

Anastasio

  $1,517,909    $1,517,909    $1,517,909    $1,517,909

Blank

  620,799    620,799    620,799    620,799

Bluntzer

  543,878    543,878    543,878    543,878

Brattlof

  503,551    503,551    503,551    503,551

Brown

  522,452    522,452    522,452    522,452
             
             

Executive Benefits and
Payments
Termination of
Employment by the
Company Other Than
for “Cause” or
Disability, or by the
Executive for “Good
Reason” (2)
Termination of
Employment because
of Death or
Disability (3)
Termination by the
Executive Other
Than for “Good
Reason” (4)
Continued
Employment
Following
Change of
Control (5)

Accelerated Vesting of Unit   Options (7)

Anastasio

Barron

Blank

Bluntzer

Morgan

$0 

$0 

$0 

$0 

Accelerated Vesting of Restricted Units (8)

Anastasio

Barron

Blank

Bluntzer

Morgan

$948,409 

276,276 

416,349 

346,701 

352,532 

$948,409 

276,276 

416,349 

346,701 

352,532 

$948,409 

276,276 

416,349 

346,701 

352,532 

$948,409 

276,276 

416,349 

346,701 

352,532 

Accelerated Vesting of Performance Units (9)

Anastasio

Barron

Blank

Bluntzer

Morgan

$370,484 

113,161 

172,329 

139,152 

123,826 

$370,484 

113,161 

172,329 

139,152 

123,826 

$370,484 

113,161 

172,329 

139,152 

123,826 

$370,484 

113,161 

172,329 

139,152 

123,826 

280G Tax Gross-Up (10)

Anastasio

Barron

Blank

Bluntzer

Morgan

$0 

812,698 

$0 

$0 

$0 

Totals

Anastasio

Barron

Blank

Bluntzer

Morgan

$4,659,993 

2,275,604 

2,058,006 

1,997,699 

1,763,430 

$1,712,013 

564,937 

827,202 

680,853 

671,358 

$1,712,013 

564,937 

827,202 

680,853 

671,358 

$1,712,013 

564,937 

827,202 

680,853 

671,358 

Executive Benefits and Payments    

Termination of

Employment by the

Company Other Than for

“Cause” or Disability, or by

the Executive for “Good

Reason” (2)

  

Termination of

Employment because of

Death or Disability (3)

  

Termination by the

Executive Other Than

for “Good Reason” (4)

  

Continued

Employment

Following Change of
Control (5)

Accelerated Vesting of Performance Units (9)            

Anastasio

  $966,319    $966,319    $966,319    $966,319  

Blank

  396,780    396,780    396,780    396,780  

Bluntzer

  344,899    344,899    344,899    344,899  

Brattlof

  303,505    303,505    303,505    303,505  

Brown

  317,526    317,526    317,526    317,526  
             
             

280G Tax Gross-Up (10)

            

Anastasio

  $0    $0    $0    $0  

Blank

  0    0    0    0  

Bluntzer

  1,159,396    0    0    0  

Brattlof

  0    0    0    0  

Brown

  0    0    0    0  
             
             

Totals

            

Anastasio

  $5,908,479    $2,878,096    $2,878,096    $2,878,096  

Blank

  2,519,650    1,176,944    1,176,944    1,176,944  

Bluntzer

  3,464,656    1,019,051    1,019,051    1,019,051  

Brattlof

  1,995,255    937,056    937,056    937,056  

Brown

  2,091,435    969,978    969,978    969,978  
             
             

Footnotes:

 

 (1)

Per SEC regulations, for purposes of this analysis we assumed each executive’s compensation at the time of each triggering event to be as stated below. The listed salary is the executive’s actual annualized rate of pay as of December 31, 2008.2009. The listed bonus amount represents the highest bonus earned by the executive in any of the fiscal years 2006, 2007, 2008 or 20082009 (the three years prior to the assumed change of control):

name

  

annual salary

  

bonus

Name

  

Annual salary

     

Bonus

Anastasio

  $460,000  $393,120  $473,800    $393,120

Barron

    265,000    175,500

Blank

    331,000    238,524  340,900    238,524

Bluntzer

    296,600    195,000  305,500    195,000

Morgan

    296,600    195,000

Brattlof

  289,600    195,000

Brown

  305,500    195,000

 

 (2)

Mr. Anastasio’s agreement provides thatThe change of control agreements provide that if the company terminates histhe executive officer’s employment (other than for “cause,” death or “disability,” as defined in the agreement) or if hethe executive officer terminates his or her employment for “good reason,” as defined in the agreement, Mr. Anastasiothe executive is generally entitled to receive the following: (A) a lump sum cash payment equal to the sum of

(A) a lump sum cash payment equal to the sum of:

(i)accrued and unpaid compensation through the date of termination, including a pro-rata annual bonus (for this table, we assumed that the executive officers’ bonuses for the year of termination of employment was deemed to occur on the last day of the year; thus a full year’s bonus is shown for this element of compensation)were paid at year end);

(ii) threetwo times the sum of the executive officer’s (three times for Mr. Anastasio’sAnastasio) annual base salary plus Mr. Anastasio’sthe executive officer’s highest annual bonus from the past three years,

(iii)the amount of the actuarial present value of the pension benefits (qualified and nonqualified) Mr. Anastasiothe executive would have received for an additional threetwo years of service (three years for Mr. Anastasio), and (iv) the equivalent of threetwo years (three years for Mr. Anastasio) of employer contributions under NuStar GP, LLC’s tax-qualified and supplemental defined contribution plans; and (B) continued welfare benefits for three years.

Other than for Mr. Anastasio, the agreements generally provide that if the company terminates the executive’s employment (other than for “cause,” death or “disability,” as defined in the agreement) or if the executive terminates his or her employment for “good reason,” as defined in the agreement, the executive is generally entitled to receive the following: (A) a lump sum cash payment equal to the sum of (i) accrued and unpaid compensation through the date of termination, including a pro-rata annual bonus (for this table, termination of employment was deemed to occur on the last day of the year; thus a full year’s bonus is shown for this element of compensation); (ii) two times the sum of the executive’s annual base salary plus the executive’s highest annual bonus from the past three years, (iii) the amount of the actuarial present value of the pension benefits (qualified and nonqualified) the executive would have received for an additional two years of service, and (iv) the equivalent of two years of employer contributions under NuStar GP, LLC’s tax-qualified and supplemental defined contribution plans; and (B) continued welfare benefits for two years.years (three years for Mr. Anastasio).

 (3)

If the executive’s employment is terminated by reason of his death or disability, then his or her estate or beneficiaries will be entitled to receive a lump sum cash payment equal to any accrued and unpaid salary and vacation pay plus a bonus equal to the highest bonus earned by the executive in the prior three years (prorated to the date of termination). In this example, the termination of employment was deemed to occur on the last day of the year; thus a full year’s bonus is shown in the table. In addition, in the case of disability, the executive would be entitled to any disability and related benefits at least as favorable as those provided by NuStar GP, LLC under its plans and programs during the 120-days prior to the executive’s termination of employment.

 (4)

If the executive voluntarily terminates his employment other than for “good reason,” then he or she will be entitled to a lump sum cash payment equal to any accrued and unpaid salary and vacation pay plus a bonus equal to the highest bonus earned by the executive in the prior three years (prorated to the date of termination). In this example, the termination of employment was deemed to occur on the last day of the year; thus a full year’s bonus is shown in the table.

 (5)

The change of control agreements provide for a three-year term of employment following a change of control. The agreements generally provide that the executive will continue to enjoy compensation and benefits on terms at least as favorable as in effect prior to the change of control. In addition, all outstanding equity incentive awards will automatically vest on the date of the change of control.

 (6)

The executive is entitled to coverage under the welfare benefit plans (e.g., health, dental, etc.) for two years following the date of termination (three years for Mr. Anastasio).

 (7)

The amounts stated in the table below represent the gross value of previously unvested unit options derived by multiplying (x) the difference between the(as applicable) $56.09 (the closing price of NuStar Energy L.P.’s units or NuStar GP Holdings, LLC units, as applicable, on the NYSE on December 31, 20082009) or $26.92 (the closing price of NuStar GP Holdings, LLC’s units on the NYSE on December 31, 2009), and the options’ exercise prices, times (y) the number of unvested unit options.

 

Name

 

Gross Value of Previously

Unvested Options

Anastasio

-997,199

Barron

 -510,276-263,741

Blank

 -683,149-191,533

Bluntzer

-564,740

Morgan

 -571,123-163,308

Brattlof

-175,371

Brown

-179,371

 (8)

The amounts stated in the table represent the gross value of previously unvested restricted units, derived by multiplying (x) the number of units whose restrictions lapsed because of the change of control, andtimes (y) the(as applicable) $56.09 (the closing price of NuStar Energy L.P.’s units or NuStar GP Holdings, LLC’s units, as applicable, on the NYSE on December 31, 2008.

2009) or $26.92 (the closing price of NuStar GP Holdings, LLC’s units on the NYSE on December 31, 2009).

 (9)

The amounts stated in the table represent the product of (x) the number of performance units whose vesting was accelerated because of the change of control, times 200%, times (y) the$56.09 (the closing price of NuStar Energy L.P.’s units on the NYSE on December 31, 2008. Based upon 2008 performance, 50% of the performance units were awarded. For the remainder of the performance period, the 2009 and 2010 fiscal years, 200% of the performance units would be awarded because of the change of control assumed here.

2009).

 (10)

If any payment or benefit is determined to be subject to an excise tax under Section 4999 of the Internal Revenue Code, of 1986, as amended, the executive is entitled to receive an additional payment to adjust for the incremental tax cost of the payment or benefit. However, if the value of all parachute payments exceeds the safe harbor threshold by less than 110%, the amounts payable to an executive will be reduced so as to not exceed the safe harbor. The reduction will eliminate any excise tax under Section 4999.

COMPENSATION OF DIRECTORS

DIRECTOR COMPENSATION (2008)(2009)

The following table provides a summary of compensation paid for the year ended December 31, 2008,2009, to the Board. The table shows amounts earned by such persons for services rendered to NuStar GP, LLC in all capacities in which they served.

 

Name and Principal Position  Fees Earned  
or Paid in
Cash ($)(1)
  Unit Awards  
($)(3)
  Option
Awards  
($)(3)
  Non-Equity
Incentive Plan
Compensation  
($)
  Change in
Pension Value
and Nonqualified  
Deferred
Compensation
Earnings ($)
  All Other
Compensation  
($)
    Total ($)  Fees Earned or
Paid in Cash
($)(1)
  Unit Awards
($)(3)
  Option
Awards ($)(3)
  Non-Equity
Incentive Plan
Compensation ($)  
  Change in Pension
Value and
Nonqualified
Deferred
Compensation
Earnings ($)
  All Other
Compensation ($)
  Total ($)            

William E. Greehey

  81,495   70,416   0  0  n/a  0    151,911  98,000    74,971    0  0  n/a  0  172,971  

Curtis V. Anastasio

  (2)  (2)  (2)  (2)  (2)  (2)    (2)  (2)  (2)  (2)  (2)  (2)  (2)  (2)

J. Dan Bates

  69,750   70,085   0  0  n/a  0    139,835  75,750    49,999    0  0  n/a  0  125,749  

Dan J. Hill

  69,341   73,041   0  0  n/a  0    142,382  75,750    49,999    0  0  n/a  0  125,749  

Stan L. McLelland

  49,750   74,127   0  0  n/a  0    123,877  51,750    49,999    0  0  n/a  0  101,749  

Rodman D. Patton

  74,876   73,041   0  0  n/a  0    147,917  75,000    49,999    0  0  n/a  0  124,999  

 

 (1)

In addition to the fees paid according to the non-employee director compensation described below, the amounts disclosed in this column include reimbursement for expenses for transportation to and from Board meetings and lodging while attending meetings.

 (2)

Mr. Anastasio is not compensated for his service as a director of NuStar GP, LLC. His compensation for his services as President and CEO are included above in the Summary Compensation Table.

 (3)

Represents dollarThe amounts recognized byreported represent the grant date fair value for the grant of restricted NuStar Energy for financial statement reporting purposesL.P. units for the fiscal year ended December 31, 2008.2009. Please see “Compensation Discussion and Analysis- Impact of Accounting and Tax Treatment- Accounting Treatment” above in this item for more information.

As of December 31, 2008,2009, each director holds the following aggregate number of restricted unit and option awards:

 

Name  Aggregate # of
Restricted Units
  Aggregate # of Unit
Options
    

Aggregate # of Restricted    

Units

 

Aggregate # of Unit Options

 

William E. Greehey

  1,725      2,368   0  

Curtis V. Anastasio

       *   *  

J. Dan Bates

  1,770      1,907   0  

Dan J. Hill

  1,725      1,907   0  

Stan L. McLelland

  1,725      1,907   0  

Rodman D. Patton

  1,725      1,907   0  

*  Mr. Anastasio’s aggregate holdings are disclosed above in the Outstanding Equity Awards at December 31, 2008.

*Mr. Anastasio’s aggregate holdings are disclosed above in the Outstanding Equity Awards at December 31, 2009.

During 2008,2009, non-employee directors received a retainer fee of $45,000 per year, plus $1,250 for each Board and committee meeting attended in person and $500 for each Board and committee meeting attended telephonically. Directors who serve as chairperson of a committee receive an additional $10,000 annually. Each director is also reimbursed for expenses of meeting attendance. Directors who are employees of NuStar GP, LLC receive no compensation (other than reimbursement of expenses) for serving as directors. The Chairman of the Board receives an additional retainer fee of $30,000$50,000 per year. The Chairman of the Board receives no fees for attending committee meetings.

NuStar GP, LLC supplements the compensation paid to non-employee directors other than the Chairman of the Board with an annual grant of restricted NuStar Energy L.P. units valued at $50,000 that vests in equal annual installments over a three-year period. The Chairman of the Board receives an annual grant of restricted NuStar Energy L.P. units valued at $75,000 that vests in equal annual installments over a three-year period. We believe this annual grant of restricted units increases the non-employee directors’ identification with the interests of NuStar Energy L.P.’s unitholders through ownership of NuStar Energy L.P. units. Upon a non-employee director’s initial election to the Board, the director will receive a grant of restricted units equal to the pro-rated amount of the annual grant of restricted units from the time of his or her election through the next annual grant of restricted units.

In the event of a “Change of Control” as defined in the 2000 LTIP, all unvested restricted units and unit options previously granted immediately become vested or exercisable. Each plan also contains anti-dilution provisions providing for an adjustment in the number of restricted units or unit options, respectively, that have been granted to prevent dilution of benefits in the event any change in the capital structure of NuStar Energy affects the NuStar Energy L.P. units.

Compensation Committee

The Compensation Committee reviews and reports to the Board on matters related to compensation strategies, policies and programs, including certain personnel policies and policy controls, management development, management succession and benefit programs. The Compensation Committee also approves and administers NuStar Energy’s equity compensation plans and incentive bonus plan. The Board has adopted a written charter for the Compensation Committee. The members of the Compensation Committee are Dan J. Hill (Chairman), J. Dan Bates and Rodman D. Patton, none of whom is a current or former employee or officer of NuStar GP, LLC. The Compensation Committee met five times in 2008.2009.

Compensation Committee Interlocks and Insider Participation

There are no compensation committee interlocks. None of Dan J.Mr. Hill, J. DanMr. Bates or Rodman D.Mr. Patton has served as an officer or employee of NuStar GP, LLC. Furthermore, except for compensation arrangements disclosed in this annual report on Form 10-K, NuStar Energy has not participated in any contracts, loans, fees, awards or financial interests, direct or indirect, with any committee member, nor is NuStar Energy aware of any means, directly or indirectly, by which a committee member could receive a material benefit from NuStar Energy.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED UNITHOLDER MATTERS

DIRECTORS AND EXECUTIVE OFFICERS

The following table sets forth ownership of NuStar Energy L.P. units and NuStar GP Holdings, LLC units by directors and executive officers of NuStar GP, LLC as of December 31, 2008.2009. Unless otherwise indicated in the notes to the table, each of the named persons and members of the group has sole voting and investment power with respect to the units shown:

 

Name of Beneficial Owner (a)

  Units
Beneficially
Owned
(b)(c)
  Units
under
Exercisable
Options (d)
  Percentage of
Outstanding
Units (c)
  NuStar GP
Holdings, LLC
Units
Beneficially
Owned
  NuStar GP
Holdings, LLC
Units under
Exercisable
Options
  Percentage of
Outstanding
Units (e)

Name of Beneficial

Owner(a)

    Units
Beneficially
Owned
(b)(c)
    Units under
Exercisable
Options(d)
    Percentage
of
Outstanding
Units(c)
    NuStar GP
Holdings,
LLC Units
Beneficially
Owned
    NuStar GP
Holdings,
LLC Units
under
Exercisable
Options
    Percentage
of
Outstanding
Units(e)
William E. Greehey    723,871      0      1.20%      6,945,276      0      16.32%  

William E. Greehey

  622,487  0  1.14%  6,878,920  0  16.17%

Curtis V. Anastasio

  52,553  55,970  *  58,915  0  *    62,216      62,785      *      65,415      0      *  

J. Dan Bates

  3,559  0  *  2,000  0  *    4,682      0      *      2,000      0      *  

Dan J. Hill

  7,156  0  *  8,000  0  *    8,079      0      *      8,000      0      *  

Stan McLelland

  4,568  0  *  14,807  0  *    5,491      0      *      16,724      0      *  

Rodman D. Patton

  11,306  0  *  10,000  0  *    12,229      0      *      10,000      0      *  

Bradley C. Barron

  7,316  3,700  *  6,500  0  *    9,359      4,515      *      8,298      0      *  

Steven A. Blank

  26,040  27,251  *  40,400  0  *    28,584      31,096      *      42,647      0      *  

James R. Bluntzer

  10,535  14,051  *  28,000  0  *    12,903      16,400      *      30,235      0      *  

Mary F. Morgan

  11,979  6,220  *  3,500  0  *
Paul R. Brattlof    10,749      680      *      7,956      0      *  
Mary Rose Brown    11,011      680      *      47,500      0      *  
Daniel S. Oliver    5,528      400      *      1,710      0      *  

Thomas R. Shoaf

  4,134  2,495  *  3,300  0  *    5,222      3,460      *      4,205      0      *  
                             

All directors and executive officers as a group (11 persons)

  761,633  109,687  1.60%  7,107,436  0  16.72%
All directors and officers as a group (13)    889,924      120,016      1.69%      7,189,966      0      16.90%  

 

*

Indicates that the percentage of beneficial ownership does not exceed 1% of the class.

 

(a)

The business address for all beneficial owners listed above is 2330 North Loop 1604 West, San Antonio, Texas 78248.

(b)

As of December 31, 2008, 54,460,5492009, 60,210,549 NuStar Energy L.P. units were issued and outstanding. There are no classes of equity securities of NuStar Energy outstanding other than the units. The calculation for Percentage of Outstanding units includes units listed under the captions “Units Beneficially Owned” and “Units under Exercisable Options.”

(c)

Includes restrictedThis column includes units issued under NuStar Energy’s long-term incentive plans. Restricted units granted under NuStar GP, LLC’s long-term incentive plans are rights to receive NuStar Energy L.P. units upon vest and, as such, may not be disposed of or voted until vested. DoesThe column does not include units that could be acquired under options, which information is set forth in the next column.

(d)

Consisting ofThis column discloses units that may be acquired within 60 days of December 31, 20082009 through the exercise of unit options.

(e)

As of December 31, 2008,2009, 42,548,983 NuStar GP Holdings, LLC’s units were issued and outstanding. No executive officer or director owns any class of equity securities of NuStar GP Holdings other than common units. The calculation for Percentage of Outstanding Units includes units listed under the captions “NuStar GP Holdings, LLC Units Beneficially Owned” and “NuStar GP Holdings, LLC Units under Exercisable Options.”

Except as otherwise indicated, the following table sets forth certain information as of December 31, 20082009 with respect to each entity known to us to be the beneficial owner of more than 5% of our outstanding units.

 

Name and Address of Beneficial Owner

 

Units

 

Percentage of
Units (b)

  

                    Units                     

  

Percentage of

Units (b)

NuStar GP Holdings(a)

2330 North Loop 1604 West

San Antonio, Texas 78248

 10,250,054 18.5%  10,257,207  17.0%

 

(a)

NuStar GP Holdings owns the units through its wholly owned subsidiaries, NuStar GP, LLC and Riverwalk Holdings, LLC. NuStar GP Holdings controls voting and investment power of the units through these wholly owned subsidiaries.

(b)

Assumes 54,460,54960,210,549 units outstanding.

EQUITY COMPENSATION PLAN INFORMATION

The following table sets forth information about NuStar GP, LLC’s equity compensation plans, which are described in further detail in Note 1517 of Notes to Consolidated Financial Statements in Item 8. “Financial Statements and Supplementary Data:”

 

Plan categories

  Number of Securities to
be issued upon exercise of
outstanding unit options,
warrants and rights
  Weighted-Average
exercise price of
outstanding unit options,
warrants and rights
  Number of securities
remaining for future
issuance under equity
compensation plans
   Number of Securities to be
issued upon exercise of
outstanding unit options,

warrants and rights(1)
  Weighted-Average exercise price
of outstanding

unit options, warrants and rights
  Number of securities
remaining for future
issuance under equity

compensation plans
Equity Compensation Plans approved by security holders  1,059,179  48.73  471,117   1,205,606  50.91  294,394
Equity Compensation Plans not approved by security holders  439,516  49.01  260,484(a)  444,423  47.91  255,577(2)

 

(a)(1)

Grants under NuStar GP, LLC’s long-term incentive plans do not dilute the interests of NuStar Energy L.P. unitholders. Upon the vest of a restricted unit or the exercise of a unit option granted under NuStar GP, LLC’s plan, NuStar GP, LLC purchases a NuStar Energy L.P. unit to satisfy that vest or exercise on the open market. No new NuStar Energy L.P. units are issued to satisfy vesting restricted units or exercises of unit options.

(2)As of December 31, 2008,2009, options to purchase 765 NuStar Energy L.P. units remained available for grant under the 2002 Unit Option Plan. As of December 31, 2008, 259,7192009, 254,812 units remained available for grant under the 2003 Employee Unit Incentive Plan.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE

TRANSACTIONS WITH MANAGEMENT AND OTHERS

In January 2007, our Board adopted a written related person transaction policy that codifies our prior practice. For purposes of the policy, a related person transaction is one that is not available to all employees generally or involvinginvolves less than $10,000 when aggregated with similar transactions. The policy requires that any related person transaction between NuStar Energy or NuStar GP, LLC and: (i) any vice president, Section 16 officer or director, (ii) any 5% or greater unitholder of NuStar Energy, its controlled affiliates or NuStar GP Holdings, (iii) any immediate family member of any officer or director, or (iv) any entity controlled by any of (i), (ii) or (iii) (or in which any of (i), (ii) or (iii) owns more than 5%) must be approved by the disinterested members of the Board. In addition, the policy requires that the officers and directors have an affirmative obligation to inform our Corporate Secretary of his or her immediate family members, as well as any entities in which he or she controls or owns more than 5%.

Please see “Executive Compensation, Potential Payments upon Termination or Change in Control” for a discussion of NuStar Energy’s Change of Control Agreements with the named executive officers.

On December 10, 2007, NuStar Logistics, L.P., our wholly owned subsidiary, entered into a non-exclusive Aircraft Time Sharing Agreement (the Time Share Agreement) with William E. Greehey, Chairman of our Board. The Time Share Agreement provides that NuStar Logistics, L.P. will sublease the aircraft to Mr. Greehey on an “as needed and as available” basis, and will provide a fully qualified flight crew for all Mr. Greehey’s flights. Mr. Greehey will pay NuStar Logistics an amount equal to the maximum amount of expense reimbursement permitted in accordance with Section 91.501(d) of the Aeronautics Regulations of the Federal Aviation Administration and the Department of Transportation, which expenses include and are limited to: fuel oil, lubricants, and other additives; travel expenses of the crew, including food, lodging and ground transportation; hangar and tie down costs away from the aircraft’s base of operation; insurance obtained for the specific flight; landing fees, airport taxes and similar assessments; customs, foreign permit, and similar fees directly related to the flight; in-flight food and beverages; passenger ground transportation; flight planning and weather contract services; and an additional charge equal to 100% of the costs of the fuel oil, lubricants, and other additives. The Time Share Agreement has an initial term of two years, after which the Time Share Agreement will automatically renew for one-year terms until terminated by either party. The Time Share Agreement was approved by the disinterested members of the Board on December 5, 2007. The Time Share Agreement was amended, as of September 4, 2009, to reflect the addition of another aircraft.

Effective on September 16, 2007, NuStar Logistics entered into an assignment and assumption agreement (the Assignment) with Valero Energy, pursuant to which NuStar Logistics, L.P. assumed certain of Valero Energy’s obligations under a letter agreement between Valero Energy and Mr. Greehey regarding his resignation from employment with Valero Energy (the Letter Agreement). Under the Letter Agreement, Valero Energy agreed to provide Mr. Greehey with “off-site office facilities and secretarial and other office services reasonably commensurate with Mr. Greehey’s position as retired CEO of Valero Energy (the Office Services). Since we moved our headquarters out of Valero Energy’s corporate headquarters in April 2007, we have provided office space for Mr. Greehey, the cost of which we billed to Valero Energy. In order to further simplify the relationship between us and Valero Energy, we assumed responsibility for the Office Services, for which Valero Energy paid us $1.2 million, the operating expense associated with providing Office Services to Mr. Greehey. The Conflicts Committee, consisting of the disinterested members of the Board, approved the Assignment on August 24, 2007.

On April 24, 2008, the independent directors of NuStar GP, LLC approved the adoption of a Services Agreement, effective January 1, 2008, between NuStar GP, LLC and NuStar Energy (the Services Agreement). The Services Agreement provides that NuStar GP, LLC will furnish all services necessary for the conduct of the business of NuStar Energy, and NuStar Energy will reimburse NuStar GP, LLC for all payroll and related benefit costs, including pension and unit-based compensation costs, other than the expenses allocated to NuStar Holdings (the Holdco Administrative Services Expense). For fiscal year 2008,2009, the Holdco Administrative Services Expense was equal to $750,000, plus 1.0% of NuStar GP, LLC’s domestic employee bonus and unit compensation expense for the 2008 fiscal year.$1.35 million. For the 20092010 fiscal year and each fiscal year thereafter, the Holdco Administrative Services Expense is equal to $1.1 million (as adjusted), plus 1.0% of NuStar GP, LLC’s domestic

domestic employee bonus and unit compensation expense for the applicable fiscal year. The Holdco Administrative Services expense is subject to adjustment (a) by an annual amount equal to NuStar GP, LLC’s annual merit increase percentage for the most recently completed contract year and (b) for changed levels of services due to expansion of operations through, among other things, expansion of operations, acquisitions or the construction of new businesses or assets. The Services Agreement will terminate December 31, 2012, with automatic two-year renewals unless terminated by either party on six months’ written notice.

RIGHTS OF NUSTAR GP HOLDINGS

Due to its ownership of NuStar GP, LLC and Riverwalk Holdings, LLC, as of December 31, 2008,2009, NuStar GP Holdings indirectly owns:

the 2% general partner interest in NuStar Energy, through its indirect 100% ownership interest in Riverwalk Logistics, L.P.;

100% of the incentive distribution rights issued by us, which entitles NuStar GP Holdings to receive increasing percentages of the cash we distribute, currently at the maximum percentage of 23%; and

10,250,05410,257,207 NuStar Energy L.P. units representing a 18.5% limited partner interest in17.0% of the issued and outstanding NuStar Energy.Energy common units.

Certain of our officers are also officers of NuStar GP Holdings. Our Chairman, William E. Greehey, is also the Chairman of NuStar GP Holdings. NuStar GP Holdings appoints NuStar GP, LLC’s directors. NuStar GP, LLC’s board is responsible for overseeing NuStar GP, LLC’s role as the owner of the general partner of NuStar Energy. NuStar GP Holdings must also approve matters that have or would have reasonably expected to have a material effect on NuStar GP Holdings’ interests as one of our major unitholders.

NuStar Energy’s partnership agreement requires that NuStar GP, LLC maintain a Conflicts Committee, composed entirely of independent directors, to review and resolve certain potential conflicts of interest between Riverwalk Logistics, L.P. and its affiliates, on one hand, and NuStar Energy, on the other hand.

DIRECTOR INDEPENDENCE

Our business is managed under the direction of the Board of NuStar GP, LLC, the general partner of Riverwalk Logistics, L.P., the general partner of NuStar Energy. The Board conducts its business through meetings of the Board and its committees. During 2008,2009, the Board held tensix meetings. No member of the Board attended less than 75% of the meetings of the Board and committees of which he was a member.

The Board has standing Audit and Compensation committees.Committees. Each committee has a written charter. The committees of the Board and the number of meetings held by the committees in 20082009 are described below.

Independent Directors

The Board has one member of management, Curtis V. Anastasio, President and CEO, and five non-management directors. The Board has determined that three of five of its non-management directors meet the independence requirements of the NYSE listing standards as set forth in the NYSE Listed Company Manual. As a limited partnership, NuStar Energy is not required to have a majority of independent directors. The independent directors are: J. Dan Bates, Dan J. Hill and Rodman D. Patton.

William E. Greehey, Chairman of the Board, retired as CEO of Valero Energy at the end of 2005. He remained Chairman of Valero Energy’s board of directors until January 2007. Valero Energy is a customer of NuStar Energy, accounting for approximately 8% of total revenues for the year ended December 31, 2008. Mr. Greehey also serves as the Chairman of the NuStar GP Holdings board of directors.directors and owns 16.32% of NuStar GP Holdings.

Curtis V. Anastasio has been President of NuStar GP, LLC since December 1999 and CEO since June 2000. As a member of management, Mr. Anastasio is not an independent director under the NYSE’s listing standards. Mr. Anastasio also serves as President and CEO of NuStar GP Holdings.

Stan L. McLelland has been a member of the Board since October 2005. In July 2006, Mr. McLelland also became a member of the board of directors of NuStar GP Holdings. Mr. McLelland stepped down from the

Audit and Compensation Committees of NuStar GP, LLC when he joined the NuStar GP Holdings board of directors.

The Audit and Compensation committees of the Board are each composed entirely of directors who meet the independence requirements of the NYSE listing standards. Each member of the Audit Committee also meets the additional independence standards for Audit Committee members set forth in the regulations of the SEC. For further information about the committees, see also Item 10 and Item 11 above.

Independence Determinations

Under the NYSE’s listing standards, no director qualifies as independent unless the Board affirmatively determines that the director has no material relationship with NuStar Energy. Based upon information requested from and provided by each director concerning their background, employment and affiliations, including commercial, industrial, banking, consulting, legal, accounting, charitable and familial relationships, the Board has determined that, other than being a director of NuStar GP, LLC and/or unitholder of NuStar Energy, each of the independent directors named above has either no relationship with NuStar Energy, either directly or as a partner, unitholder or officer of an organization that has a relationship with NuStar Energy, or has only immaterial relationships with NuStar Energy, and is therefore independent under the NYSE’s listing standards.

As provided for under the NYSE listing standards, the Board has adopted categorical standards or guidelines to assist the Board in making its independence determinations with respect to each director. Under the NYSE listing standards, immaterial relationships that fall within the guidelines are not required to be disclosed in this proxy statement.

A relationship falls within the guidelines adopted by the Board if it:

 

is not a relationship that would preclude a determination of independence under Section 303A.02(b) of the NYSE Listed Company Manual;

 

consists of charitable contributions by NuStar GP, LLC to an organization where a director is an executive officer and does not exceed the greater of $1 million or 2% of the organization’s gross revenue in any of the last three years;

 

consists of charitable contributions to any organization with which a director, or any member of a director’s immediate family, is affiliated as an officer, director or trustee pursuant to a matching gift program of NuStar GP, LLC and made on terms applicable to employees and directors; or is in amounts that do not exceed $250,000 per year; and

 

is not required to be, and it is not otherwise, disclosed in this annual report on Form 10-K.

NuStar GP, LLC’s Corporate Governance Guidelines contain the director qualification standards, including the guidelines listed above, and are available on NuStar Energy’s internet website athttp://www.nustarenergy.com (in the “Investor Relations” section) or are available in print upon request to NuStar GP, LLC’s Corporate Secretary at the address indicated on the cover page of this annual report on Form 10-K.

Presiding Director/Meetings of Non-Management Directors

The Board has designated Mr. Patton to serve as the Presiding Director for meetings of the non-management Board members outside the presence of management.

Communications with the Board, Non-Management Directors or Presiding Director

Unitholders and other interested parties may communicate with the Board, the non-management directors or the Presiding Director by sending a written communication in an envelope addressed to “Board of Directors,” “Non-Management Directors,” or “Presiding Director” in care of NuStar GP, LLC’s Corporate Secretary at the address indicated on the cover page of this annual report on Form 10-K.

Availability of Governance Documents

NuStar Energy has posted its Corporate Governance Guidelines, Code of Business Conduct and Ethics, Code of Ethics of Senior Financial Officers, the Audit Committee Charter and other governance documents on NuStar Energy’s internet website athttp://www.nustarenergy.com (in the “Investor Relations” section). NuStar

Energy’s governance documents are available in print to any unitholder of record who makes a written request to NuStar Energy. Requests must be directed to NuStar GP, LLC’s Corporate Secretary at the address indicated on the cover page of this annual report on Form 10-K.

ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES

KPMG FEES FOR FISCAL YEAR 2009

Audit Fees

The aggregate fees for fiscal year 2009 for professional services rendered by KPMG for the audit of the annual financial statements for the year ended December 31, 2009 included in this Form 10-K, review of NuStar Energy’s interim financial statements included in NuStar Energy’s 2009 Forms 10-Q, the audit of the effectiveness of NuStar Energy’s internal control over financial reporting as of December 31, 2009 and related services that are normally provided by the principal auditor (e.g., comfort letters and assistance with review of documents filed with the SEC) were $1,994,200.

Audit-related Fees

The aggregate fees for the fiscal year 2009 for assurance and related services rendered by KPMG that are reasonably related to the performance of the audit or review of NuStar Energy’s financial statements and not reported in the preceding caption were $0.

Tax Fees

The aggregate fees for the fiscal year 2009 for professional services rendered by KPMG for tax compliance, tax advice and tax planning were $0.

All Other Fees

The aggregate fees for the fiscal year 2009 for services rendered by KPMG, other than the services reported under the preceding captions, were $0.

KPMG FEES FOR FISCAL YEAR 2008

Audit Fees

The aggregate fees for fiscal year 2008 for professional services rendered by KPMG for the audit of the annual financial statements for the year ended December 31, 2008 included in this Form 10-K, review of NuStar Energy’s interim financial statements included in NuStar Energy’s 2008 Forms 10-Q, the audit of the effectiveness of NuStar Energy’s internal control over financial reporting as of December 31, 2008 and related services that are normally provided by the principal auditor (e.g., comfort letters and assistance with review of documents filed with the SEC) were $2,097,546.

Audit-related Fees

The aggregate fees for the fiscal year 2008 for assurance and related services rendered by KPMG that are reasonably related to the performance of the audit or review of NuStar Energy’s financial statements and not reported in the preceding caption were $245,000. The fees related primarily to audit fees incurred for Kaneb benefit plans and the audit of assets and operations acquired from CITGO Asphalt Refining Company on March 20, 2008.

Tax Fees

The aggregate fees for the fiscal year 2008 for professional services rendered by KPMG for tax compliance, tax advice and tax planning were $23,895.

All Other Fees

The aggregate fees for the fiscal year 2008 for services rendered by KPMG, other than the services reported under the preceding captions, were $0.

KPMG FEES FOR FISCAL YEAR 2007

Audit Fees

The aggregate fees for fiscal year 2007 for professional services rendered by KPMG for the audit of the annual financial statements for the year ended December 31, 2007 included in this Form 10-K, review of NuStar Energy’s interim financial statements included in NuStar Energy’s 2007 Forms 10-Q, the audit of the effectiveness of NuStar Energy’s internal control over financial reporting as of December 31, 2007 and related services that are normally provided by the principal auditor (e.g., comfort letters and assistance with review of documents filed with the SEC) were $1,743,930.

Audit-related Fees

The aggregate fees for the fiscal year 2007 for assurance and related services rendered by KPMG that are reasonably related to the performance of the audit or review of NuStar Energy’s financial statements and not reported in the preceding caption were $242,693. The fees related primarily to consultations for technical accounting issues and audit fees incurred for Kaneb benefit plans.

Tax Fees

The aggregate fees for the fiscal year 2007 for professional services rendered by KPMG for tax compliance, tax advice and tax planning were $0.

All Other Fees

The aggregate fees for the fiscal year 2007 for services rendered by KPMG, other than the services reported under the preceding captions, were $0.

AUDIT COMMITTEE PRE-APPROVAL POLICY

The audit committee has adopted a pre-approval policy to address the approval of services rendered to NuStar Energy by its independent auditors, which is filed herewith as Exhibit 99.01.

None of the services (described above) for 20072008 or 20082009 provided by KPMG were approved by the audit committee pursuant to paragraph (c)(7)(i)(C) of Rule 2-01 of Regulation S-X.

PART IV

ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

 

(a)  (1)  Financial Statements. The following consolidated financial statements of NuStar Energy L.P. and its subsidiaries are included in Part II, Item 8 of this Form 10-K:
    

Management’s Report on Internal Control over Financial Reporting

Reports of independent registered public accounting firm (KPMG LLP)

Consolidated Balance Sheets as of December 31, 20082009 and 20072008

Consolidated Statements of Income for the Years Ended December 31, 2009, 2008 2007 and 20062007

Consolidated Statements of Cash Flows for the Years Ended December 31, 2009, 2008 2007 and 20062007

Consolidated Statements of Partners’ Equity for the Years Ended December 31, 2009, 2008 2007 and 20062007

Notes to Consolidated Financial Statements

  (2)  Financial Statement Schedules and Other Financial Information. No financial statement schedules are submitted because either they are inapplicable or because the required information is included in the consolidated financial statements or notes thereto.
  (3)  Exhibits

Filed as part of this Form 10-K are the following:

 

Exhibit

Number

  

Description

  

Incorporated by Reference

to the Following Document

2.01  Agreement and Plan of Merger, dated as of October 31, 2004, by and among Valero L.P., Riverwalk Logistics, L.P., Valero GP, LLC, VLI Sub A LLC and Kaneb Services LLC  NuStar Energy L.P.’s Current Report on Form 8-K filed November 4, 2004 (File No. 001-16417), Exhibit 99.1
2.02  Agreement and Plan of Merger, dated as of October 31, 2004, by and among Valero L.P., Riverwalk Logistics, L.P., Valero GP, LLC, VLI Sub B LLC and Kaneb Pipe Line Partners, L.P. and Kaneb Pipe Line Company LLC  NuStar Energy L.P.’s Current Report on Form 8-K filed November 4, 2004 (File No. 001-16417), Exhibit 99.2
3.01  Certificate of Formation of UDS Logistics, LLC  NuStar GP Holdings, LLC’s Registration Statement on Form S-1 filed on March 31, 2006 (File No. 333-132917), Exhibit 3.01
3.02  Certificate of Amendment to Certificate of Formation of UDS Logistics, LLC  NuStar GP Holdings, LLC’s Registration Statement on Form S-1 filed on March 31, 2006 (File No. 333-132917), Exhibit 3.03
3.03  Amended and Restated Certificate of Limited Partnership of Valero L.P.  NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2001 (File No. 001-16417), Exhibit 3.3
3.04  Amendment to Amended and Restated Certificate of Limited Partnership of Valero L.P., dated March 21, 2007 and effective April 1, 2007  NuStar Energy L.P.’s Current Report on Form 8-K, filed March 27, 2007 (File No. 001-16417), Exhibit 3.01

Exhibit

Number

  

Description

  

Incorporated by Reference

to the Following Document

3.05  Third Amended and Restated Agreement of Limited Partnership of Valero L.P.  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2003 (File No. 001-16417), Exhibit 3.1
3.06  First Amendment to Third Amended and Restated Agreement of Limited Partnership of Valero L.P.  NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2003 (File No. 001-16417), Exhibit 4.3
3.07  Amendment No. 2 to Third Amended and Restated Agreement of Limited Partnership of Valero L.P., dated as of July 1, 2005  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended June 30, 2005 (File No. 001-16417), Exhibit 4.01
3.08  Certificate of Limited Partnership of Valero Logistics Operations, L.P.  NuStar Energy L.P.’s Registration Statement on Form S-1 (File No. 333-43668), Exhibit 3.4
3.09  Certificate of Amendment to Certificate of Limited Partnership of Valero Logistics Operations, L.P.  NuStar Energy L.P.’s Registration Statement on Form S-1 (File No. 333-43668), Exhibit 3.5
3.10  Certificate of Amendment to Certificate of Limited Partnership of Valero Logistics Operations, L.P., dated March 21, 2007 and effective April 1, 2007  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2007, File No. 001-16417, Exhibit 3.03
3.11  Second Amended and Restated Agreement of Limited Partnership of Valero Logistics Operations, L.P.  NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2001 (File No. 001-16417), Exhibit 3.9
3.12  Second Amendment to Second Amended and Restated Agreement of Limited Partnership of Valero Logistics Operations, L.P.  NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2001 (File No. 001-16417), Exhibit 3.10
3.13  Certificate of Limited Partnership of Riverwalk Logistics, L.P.  NuStar Energy L.P.’s Registration Statement on Form S-1 (File No. 333-43668), Exhibit 3.7
3.14  First Amended and Restated Limited Partnership Agreement of Riverwalk Logistics, L.P.  NuStar Energy L.P.’s Annual Report on Form 10-K for the year ended December 31, 2001 (File No. 001-16417), Exhibit 3.16
3.15  Certificate of Formation of Valero GP, LLC  NuStar Energy L.P.’s Registration Statement on Form S-1 (File No. 333-43668), Exhibit 3.9
3.16  Amendment to Certificate of Formation of Valero GP, LLC, dated March 21, 2007 and effective April 1, 2007  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2007, File No.001-16417, Exhibit 3.02

Exhibit

Number

  

Description

  

Incorporated by Reference

to the Following Document

3.17  Certificate of Amendment to Certificate of Formation of Valero GP, LLC  NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2001 (File No. 001-16417), Exhibit 3.14
3.18  First Amended and Restated LLC Agreement of Shamrock Logistics GP, LLC  NuStar Energy L.P.’s Registration Statement on Form S-1 (File No. 333-43668), Exhibit 3.10
3.19  First Amendment to First Amended and Restated Limited Liability Company Agreement of Valero GP, LLC  NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2001 (File No. 001-16417), Exhibit 3.15
3.20  First Amended and Restated Limited Partnership Agreement of Riverwalk Logistics, L.P.  NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2001 (File No. 001-16417), Exhibit 3.16
4.01  Indenture, dated July 15, 2002, among Valero Logistics Operations, L.P., as Issuer, Valero L.P., as Guarantor, and The Bank of New York, as Trustee, relating to Senior Debt Securities  NuStar Energy L.P.’s Current Report on Form 8-K filed July 15, 2002 (File No. 001-16417), Exhibit 4.1
4.02  First Supplemental Indenture, dated as of July 15, 2002, to Indenture dated July 15, 2002, in each case among Valero Logistics Operations, L.P., as Issuer, Valero L.P., as Guarantor, and The Bank of New York, as Trustee, relating to 6 7/8% Senior Notes Due 2012  NuStar Energy L.P.’s Current Report on Form 8-K filed July 15, 2002 (File No. 001-16417), Exhibit 4.2
4.03  Second Supplemental Indenture, dated as of March 18, 2003, to Indenture dated July 15, 2002, as amended and supplemented by a First Supplemental Indenture thereto dated as of July 15, 2002, in each case among Valero Logistics Operations, L.P., as Issuer, Valero L.P., as Guarantor, and The Bank of New York, as Trustee (including, form of global note representing $250,000,000 6.05% Senior Notes due 2013)  NuStar Energy L.P.’s Current Report on Form 8-K filed May 9, 2003 (File No. 001-16417), Exhibit 4.1
4.04  Third Supplemental Indenture, dated as of July 1, 2005, to Indenture dated July 15, 2002, as amended and supplemented, among Valero Logistics Operations, L.P.; Valero L.P.; Kaneb Pipe Line Operating Partnership, L.P.; and The Bank of New York  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2005 (File No. 001-16417), Exhibit 4.02

Exhibit

Number

  

Description

  

Incorporated by Reference

to the Following Document

4.05  Instrument of Resignation, Appointment and Acceptance, dated March 31, 2008, among NuStar Logistics, L.P., NuStar Energy L.P., Kaneb Pipeline Operating Partnership, L.P. The Bank of New York Trust Company N.A., and Wells Fargo Bank, National Association  *NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2008 (File No. 001-16417), Exhibit 4.05
4.06  Indenture, dated as of February 21, 2002, between Kaneb Pipe Line Operating Partnership, L.P. and JPMorgan Chase Bank (Senior Debt Securities)  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2005 (File No. 001-16417), Exhibit 4.03
4.07  First Supplemental Indenture, dated as of February 21, 2002, to Indenture dated as of February 21, 2002, between Kaneb Pipe Line Operating Partnership, L.P. and JPMorgan Chase Bank (including form of 7.750% Senior Unsecured Notes due 2012)  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2005 (File No. 001-16417), Exhibit 4.04
4.08  Second Supplemental Indenture, dated as of August 9, 2002 and effective as of April 4, 2002, to Indenture dated as of February 21, 2002, as amended and supplemented, between Kaneb Pipe Line Operating Partnership, L.P.; Statia Terminals Canada Partnership; and JPMorgan Chase Bank  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2005 (File No. 001-16417), Exhibit 4.05
4.09  Third Supplemental Indenture, dated and effective as of May 16, 2003, to Indenture dated as of February 21, 2002, as amended and supplemented, between Kaneb Pipe Line Operating Partnership, L.P.; Statia Terminals Canada Partnership; and JPMorgan Chase Bank  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2005 (File No. 001-16417), Exhibit 4.06
4.10  Fourth Supplemental Indenture, dated and effective as of May 27, 2003, to Indenture dated as of February 21, 2002, as amended and supplemented, between Kaneb Pipe Line Operating Partnership, L.P. and JPMorgan Chase Bank (including form of 5.875% Senior Unsecured Notes due 2013)  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2005 (File No. 001-16417), Exhibit 4.07
4.11  Fifth Supplemental Indenture, dated and effective as of July 1, 2005, to Indenture dated as of February 21, 2002, as amended and supplemented, among Kaneb Pipe Line Operating Partnership, L.P.; Valero L.P.; Valero Logistics Operations, L.P.; and JPMorgan Chase Bank  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2005 (File No. 001-16417), Exhibit 4.08

Exhibit

Number

  

Description

  

Incorporated by Reference

to the Following Document

4.12  Instrument of Resignation, Appointment and Acceptance, dated June 30, 2008, among NuStar Pipeline Operating Partnership L.P., NuStar Energy L.P., NuStar Logistics, L.P. The Bank of New York Trust Company N.A., and Wells Fargo Bank, National Association  *NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2008 (File No. 001-16417), Exhibit 4.12
4.13  Registration Rights Agreement, dated March 18, 2003, among Valero Logistics Operations, L.P., as Issuer, Valero L.P., as Guarantor, and the initial purchasers of Valero Logistics Operations, L.P. 6.05% Senior Notes due 2013  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2003 (File No. 001-16417), Exhibit 10.10
10.01  5-Year Revolving Credit Agreement dated as of December 10, 2007 among NuStar Logistics, L.P., NuStar Energy L.P., the Lenders party thereto and JPMorgan Chase Bank, N.A., as Administrative Agent, Suntrust Bank, as Syndication Agent, and Barclays Bank PLC and Mizuho Corporate Bank Ltd., as Co-Documentation Agents  NuStar Energy L.P.’s Annual Report on Form 10-K for the year ended December 31, 2007 (File No. 001-16417), Exhibit 10.01
+10.02  NuStar GP, LLC Amended and Restated 2003 Employee Unit Incentive Plan, amended and restated as of April 1, 2007  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2007 (File No. 001-16417), Exhibit 10.03
+10.03  Form of Unit Option Agreement under the Amended and Restated 2003 Employee Unit Incentive Plan  NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2006 (File No. 001-16417), Exhibit 10.1810.11
+10.04  NuStar GP, LLC Amended and Restated 2002 Unit Option Plan, amended and restated as of April 1, 2007  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2007 (File No. 001-16417), Exhibit 10.02
+10.05  NuStar GP, LLC Second Amended and Restated 2000 Long-Term Incentive Plan, amended and restated as of April 1, 2007  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2007 (File No. 001-16417), Exhibit 10.01
+10.06  Form of Restricted Unit Agreement under the NuStar GP, LLC Second Amended and Restated 2000 Long-Term Incentive Plan  NuStar Energy L.P.’s Current Report on Form 8-K filed November 10, 2008 (File No. 001-16417), Exhibit 10.03
+10.07  Form of Unit Option Award Agreement under the NuStar GP, LLC Second Amended and Restated 2000 Long-Term Incentive Plan  NuStar Energy L.P.’s Current Report on Form 8-K filed November 3, 2006 (File No. 001-16417), Exhibit 10.02
+10.08  Form of Performance Unit Agreement under the NuStar GP, LLC Amended and Restated 2000 Long-Term Incentive Plan  NuStar Energy L.P.’s Current Report on Form 8-K filed January 26, 2006 (File No. 001-16417), Exhibit 10.02
+10.09Form of Amended and Restated Performance Unit Agreement under the NuStar GP, LLC Second Amended and Restated 2000 Long-Term Incentive PlanNuStar Energy L.P.’s Current Report on Form 8-K filed December 8, 2009 (File No. 001-16417), Exhibit 10.02
+10.10Omnibus Amendment to Form of Amended and Restated Performance Unit Agreements under the NuStar GP LLC Second Amended and Restated 2000 Long-Term Incentive PlanNuStar Energy L.P.’s Current Report on Form 8-K filed February 2, 2010 (File No. 001-16417), Exhibit 10.03

Exhibit

Number

  

Description

  

Incorporated by Reference

to the Following Document

+10.0910.11Form of Performance Unit Agreement under the Second Amended and Restated 2000 Long-Term Incentive Plan*
+10.12  Form of Non-employee Director Restricted Unit Agreement under the NuStar GP, LLC Second Amended and Restated 2000 Long-Term Incentive Plan  NuStar Energy L.P.’s Current Report on Form 8-K filed November 10, 2008 (File No. 001-16417), Exhibit 10.02
+10.1010.13  NuStar Energy L.P. Bonus Plan  NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2006 (File No. 001-16417), Exhibit 10.18
+10.1110.14  Change of Control Severance Agreement by and among Valero GP, LLC, Valero L.P. and Curtis V. Anastasio, dated November 6, 2006.  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2006 (File No. 001-16417), Exhibit 10.05
+10.1210.15  Form of Change of Control Severance Agreement by and among Valero GP, LLC, Valero L.P. and each of the other executive officers of Valero GP, LLC  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2006 (File No. 001-16417), Exhibit 10.06
10.13Pipelines and Terminals Usage Agreement by and among Ultramar Diamond Shamrock Corporation, Shamrock Logistics Operations, L.P., Shamrock Logistics, L.P., Riverwalk Logistics, L.P. and Shamrock Logistics GP, LLC, dated April 16, 2001NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2001, Exhibit 10.6
10.14Fourth Amended and Restated Services Agreement among Diamond Shamrock Refining and Marketing Company, Valero L.P., Valero Logistics Operations, L.P., Riverwalk Logistics, L.P. and Valero GP, LLC, effective as of December 22, 2006NuStar Energy L.P.’s Current Report on Form 8-K filed December 22, 2006 (File No. 001-16417), Exhibit 10.01
10.15Contribution Agreement by and among Valero Refining Company–California, UDS Logistics, LLC, Valero L.P., Valero GP, Inc. and Valero Logistics Operations, L.P. dated as of March 6, 2003NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2002 (File No. 001-16417), Exhibit 10.13
10.16Contribution Agreement by and among Valero Refining Company–Texas, L.P., UDS Logistics, LLC, Valero L.P., Valero GP, Inc. and Valero Logistics Operations, L.P. dated as of March 6, 2003NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2002 (File No. 001-16417), Exhibit 10.14
10.17Contribution Agreement by and among Valero Pipeline Company, UDS Logistics, LLC, Valero L.P., Valero GP, Inc. and Valero Logistics Operations, L.P. dated as of March 6, 2003NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2002 (File No. 001-16417), Exhibit 10.15

Exhibit

Number

Description

Incorporated by Reference

to the Following Document

10.18Handling and Throughput Agreement between Valero Marketing and Supply Company and Valero Logistics Operations, L.P., dated as of March 18, 2003NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2003 (File No. 001-16417), Exhibit 10.1
10.19Amendment Number One to the Handling and Throughput Agreement between Valero Marketing and Supply Company and Valero Logistics Operations, L.P., effective as of April 27, 2004NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2004 (File No. 001-16417), Exhibit 10.3
10.20Throughput Commitment Agreement by and among Valero Marketing and Supply Company, Valero Logistics Operations, L.P. and Valero L.P., dated as of March 18, 2003NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2003 (File No. 001-16417), Exhibit 10.4
10.21Terminalling Agreement (Edinburg) between Valero Marketing and Supply Company and Valero Logistics Operations, L.P., dated as of March 18, 2003NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2003 (File No. 001-16417), Exhibit 10.5
10.22Terminalling Agreement (Houston Asphalt) between Valero Marketing and Supply Company and Valero Logistics Operations, L.P., dated as of March 18, 2003NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2003 (File No. 001-16417), Exhibit 10.6
10.23Terminalling Agreement (Hobby Airport) between Valero Marketing and Supply Company and Valero Logistics Operations, L.P., dated as of March 18, 2003NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2003 (File No. 001-16417), Exhibit 10.7
10.24Terminalling Agreement (Placedo) between Valero Marketing and Supply Company and Valero Logistics Operations, L.P., dated as of March 18, 2003NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2003 (File No. 001-16417), Exhibit 10.8
10.25Terminalling Agreement (San Antonio East) between Valero Marketing and Supply Company and Valero Logistics Operations, L.P., dated as of March 18, 2003NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2003 (File No. 001-16417), Exhibit 10.9
10.26Terminal Services Agreement executed September 20, 2006, between Valero Logistics Operations, L.P. and Valero Marketing and Supply CompanyNuStar Energy L.P.’s Current Report on Form 8-K filed October 3, 2006 (File No. 001-16417), Exhibit 10.01
10.27  Non-Compete Agreement between Valero GP Holdings, LLC, Valero L.P., Riverwalk Logistics, L.P. and Valero GP, LLC, effective as of July 19, 2006  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended September 30, 2006 (File No. 001-16417), Exhibit 10.03

Exhibit

Number

Description

Incorporated by Reference

to the Following Document

10.2810.17  Services Agreement, effective January 1, 2008, between NuStar GP, LLC and NuStar Energy L.P.  NuStar Energy L.P.’s Quarterly Report on Form 10-Q for quarter ended March 31, 2008 (File No. 001-16417), Exhibit 10.01
10.2910.18  NuStar GP, LLC Excess Pension Plan, amended and restated effective January 1, 2008  *NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2008 (File No. 001-16417), Exhibit 10.29
10.3010.19  NuStar GP, LLC Excess Thrift Plan, amended and restated effective January 1, 2008  *NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2008 (File No. 001-16417), Exhibit 10.30
10.3110.20  NuStar GP, LLC Supplemental Executive Retirement Plan, amended and restated effective January 1, 2008  *NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2008 (File No. 001-16417), Exhibit 10.31
10.3210.21  NuStar GP, LLC Short-Term Incentive Plan  NuStar Energy L.P.’s Registration Statement on Form S-1 filed March 29, 2001 (File No. 333-43668), Exhibit 10.4
10.3310.22  NuStar GP, LLC Intermediate-Term Incentive Plan  NuStar Energy L.P.’s Registration Statement on Form S-1 filed March 29, 2001 (File No. 333-43668), Exhibit 10.9

Exhibit

Number

Description

Incorporated by Reference

to the Following Document

10.3410.23  Sale and Purchase Agreement, dated as of November 5, 2007, by and between CITGO Asphalt Refining Company and NuStar Asphalt Refining, LLC  NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2008 (File No. 001-16417), Exhibit 10.37
10.3510.24  Amended and Restated Aircraft Time Sharing Agreement, dated December 10, 2007,as of September 4, 2009, between NuStar Logistics, L.P. and William E. Greehey  NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2008 (File No. 001-16417), Exhibit 10.38*
12.01  Statement of Computation of Ratio of Earnings to Fixed Charges  *
14.01  Code of Ethics for Senior Financial Officers  NuStar Energy L.P.’s Annual Report on Form 10-K for year ended December 31, 2003 (File No. 001-16417), Exhibit 14.1
21.01  List of subsidiaries of NuStar Energy L.P.  *
23.01  Consent of KPMG LLP, dated February 27, 200926, 2010  *
24.01  Powers of Attorney (included in signature page of this Form 10-K)  *
31.01  

Rule 13a-14(a) Certifications (under Section 302 of the Sarbanes-Oxley Act of

2002)

  *

Exhibit

Number

Description

Incorporated by Reference

to the Following Document

32.01  Section 1350 Certifications (under Section 906 of the Sarbanes-Oxley Act of 2002)  *
99.01  Audit Committee Pre-Approval Policy  *
99.02  Report of Independent Registered Public Accountants, Balance Sheet—December 31, 20082009 and Notes to Balance Sheet-- December 31, 20082009 of NuStar GP Holdings, LLC  *

 

*

Filed herewith.

 

+

Identifies management contracts or compensatory plans or arrangements required to be filed as an exhibit hereto pursuant to Item 15(c) of Form 10-K.

Copies of exhibits filed as a part of this Form 10-K may be obtained by unitholders of record at a charge of $0.15 per page, minimum $5.00 each request. Direct inquiries to Corporate Secretary, NuStar Energy L.P., 2330 North Loop 1604 West, San Antonio, Texas 78248.

Disclosures Required by Section 303A.12 of the NYSE Listed Company Manual. Section 303A.12 of the NYSE Listed Company Manual requires the CEO of each listed company to certify to the NYSE each year that he or she is not aware of any violation by the listed company of any of the NYSE corporate governance listing standards. The CEO of NuStar Energy L.P. submitted the required certification without qualification to the NYSE as of March 20, 2008. In addition, the CEO certification and the chief financial officer’s certification required by Section 302 of the Sarbanes-Oxley Act of 2002 (the SOX 302 Certifications) with respect to NuStar Energy L.P.’s disclosures in its Form 10-K for the year ended December 31, 2007 were filed as Exhibit 31.01 to NuStar Energy L.P.’s Form 10-K for the year ended December 31, 2007. The SOX 302 Certifications with respect to NuStar Energy L.P.’s disclosures in its Form 10-K for the year ended December 31, 2008 are being filed as Exhibit 31.01 to this Form 10-K.

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Exchange Act, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

 

NUSTAR ENERGY L.P.
(Registrant)
By: Riverwalk Logistics, L.P., its general partner
 By:NuStar GP, LLC, its general partner
By: 

    /s/ Curtis V. Anastasio

 
 (Curtis V. Anastasio) 
 President and Chief Executive Officer
 February 27, 200926, 2010 
By: 

    /s/ Steven A. Blank

 
 (Steven A. Blank) 
 Senior Vice President, Chief Financial Officer and Treasurer
 February 27, 200926, 2010 
By: 

    /s/ Thomas R. Shoaf

 
 (Thomas R. Shoaf) 
 Vice President and Controller
 February 27, 200926, 2010 

POWER OF ATTORNEY

KNOW ALL MEN BY THESE PRESENTS, that each person whose signature appears below hereby constitutes and appoints Curtis V. Anastasio, Steven A. Blank and Bradley C. Barron, or any of them, each with power to act without the other, his true and lawful attorney-in-fact and agent, with full power of substitution and resubstitution, for him and in his name, place and stead, in any and all capacities, to sign any or all subsequent amendments and supplements to this Annual Report on Form 10-K, and to file the same, or cause to be filed the same, with all exhibits thereto, and other documents in connection therewith, with the Securities and Exchange Commission, granting unto each said attorney-in-fact and agent full power to do and perform each and every act and thing requisite and necessary to be done in and about the premises, as fully to all intents and purposes as he might or could do in person, hereby qualifying and confirming all that said attorney-in-fact and agent or his substitute or substitutes may lawfully do or cause to be done by virtue hereof.

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

 

Signature

  

Title

 

Date

    /s//s/ William E. Greehey

        (William E. Greehey)

  Chairman of the Board February 27, 200926, 2010
     (William E. Greehey)

    /s//s/ Curtis V. Anastasio

        (Curtis V. Anastasio)

  President, Chief Executive
Officer and Director
(Principal Executive Officer)
 February 27, 200926, 2010
     (Curtis V. Anastasio)

Officer and Director

(Principal Executive Officer)

    /s//s/ Steven A. Blank

        (Steven A. Blank)

  Senior Vice President,
February 26, 2010
     (Steven A. Blank)

Chief Financial Officer and
Treasurer

(Principal Financial Officer)

 February 27, 2009

    /s//s/ Thomas R. Shoaf

        (Thomas R. Shoaf)

  Vice President and Controller
February 26, 2010
     (Thomas R. Shoaf)(Principal Accounting Officer) February 27, 2009

    /s//s/ J. Dan Bates

        (J. Dan Bates)

  Director February 27, 200926, 2010
     (J. Dan Bates)

    /s//s/ Dan J. Hill

        (Dan J. Hill)

  Director February 27, 200926, 2010
     (Dan J. Hill)

    /s//s/ Stan McLelland

        (Stan McLelland)

  Director February 27, 200926, 2010
     (Stan McLelland)

    /s//s/ Rodman D. Patton

        (Rodman D. Patton)

  Director February 27, 200926, 2010
     (Rodman D. Patton)

 

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