Edgar Filing: NuStar Energy L.P.

NS 3Q11 10Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

_________________________________________

FORM 10-Q

_________________________________________

(Mark One)



x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
	For the quarterly period ended September 30, 2011



o	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
(Address of principal executive offices)		(Zip Code)

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

_________________________________________

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 o

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule12b-2 of the Exchange Act:



Large accelerated filer	x	Accelerated filer	£

Non-accelerated filer	o (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 o No x

The number of common units outstanding as of October 31, 2011 was 64,718,578.

Table of Contents

NUSTAR ENERGY L.P. AND SUBSIDIARIES

FORM 10-Q

TABLE OF CONTENTS



PART I – FINANCIAL INFORMATION

Item 1.	Financial Statements:

	Consolidated Balance Sheets as of September 30, 2011 and December 31, 2010	3

	Consolidated Statements of Income for the Three and Nine Months Ended September 30, 2011 and 2010	4

	Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2011 and 2010	5

	Condensed Notes to Consolidated Financial Statements	6

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	28

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	43

Item 4.	Controls and Procedures	47

PART II – OTHER INFORMATION

Item 1.	Legal Proceedings	48

Item 6.	Exhibits	49

SIGNATURES		50

Table of Contents

PART I – FINANCIAL INFORMATION


Item 1.	Financial Statements

NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(Thousands of Dollars, Except Unit Data)



	September 30, 2011			December 31, 2010
	(Unaudited)
Assets
Current assets:
Cash and cash equivalents	$	59,214		$	181,121
Accounts receivable, net of allowance for doubtful accounts of $1,742 and $1,457 as of September 30, 2011 and December 31, 2010, respectively	467,912			302,053
Inventories	603,683			413,537
Other current assets	69,101			42,796
Total current assets	1,199,910			939,507
Property, plant and equipment, at cost	4,328,975			4,021,319
Accumulated depreciation and amortization	(943,539		)	(833,862		)
Property, plant and equipment, net	3,385,436			3,187,457
Intangible assets, net	42,499			43,033
Goodwill	846,526			813,270
Investment in joint venture	67,203			69,603
Deferred income tax asset	9,671			8,138
Other long-term assets, net	296,903			325,385
Total assets	$	5,848,148		$	5,386,393
Liabilities and Partners’ Equity
Current liabilities:
Current portion of long-term debt	$	355,645		$	832
Accounts payable	461,038			282,382
Payable to related party	12,369			10,345
Accrued interest payable	23,615			29,706
Accrued liabilities	110,934			57,953
Taxes other than income tax	16,499			10,718
Income tax payable	2,959			1,293
Total current liabilities	983,059			393,229
Long-term debt, less current portion	2,170,010			2,136,248
Long-term payable to related party	11,871			10,088
Deferred income tax liability	35,917			29,565
Other long-term liabilities	122,242			114,563
Commitments and contingencies (Note 5)
Partners’ equity:
Limited partners (64,670,520 and 64,610,549 common units outstanding as of September 30, 2011 and December 31, 2010, respectively)	2,553,995			2,598,873
General partner	56,284			57,327
Accumulated other comprehensive (loss) income	(97,912		)	46,500
Total NuStar Energy L.P. partners' equity	2,512,367			2,702,700
Noncontrolling interest	12,682			—
Total partners’ equity	2,525,049			2,702,700
Total liabilities and partners’ equity	$	5,848,148		$	5,386,393

See Condensed Notes to Consolidated Financial Statements.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME

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



	Three Months Ended September 30,						Nine Months Ended September 30,
	2011			2010			2011			2010
Revenues:
Service revenues:
Third parties	$	210,395		$	201,390		$	607,866		$	585,772
Related party	286			—			823			—
Total service revenues	210,681			201,390			608,689			585,772
Product sales	1,613,669			936,989			4,039,461			2,623,077
Total revenues	1,824,350			1,138,379			4,648,150			3,208,849
Costs and expenses:
Cost of product sales	1,535,609			860,942			3,797,424			2,422,751
Operating expenses:
Third parties	98,464			86,104			281,419			259,465
Related party	37,151			35,644			109,061			103,563
Total operating expenses	135,615			121,748			390,480			363,028
General and administrative expenses:
Third parties	8,746			9,727			27,865			28,633
Related party	8,985			17,133			41,968			47,691
Total general and administrative expenses	17,731			26,860			69,833			76,324
Depreciation and amortization expense	42,418			38,539			124,354			114,653
Total costs and expenses	1,731,373			1,048,089			4,382,091			2,976,756
Operating income	92,977			90,290			266,059			232,093
Equity in earnings of joint venture	2,599			2,454			6,997			7,571
Interest expense, net	(21,565		)	(20,583		)	(62,644		)	(58,059		)
Other income (expense), net	767			(235		)	(5,699		)	14,882
Income before income tax expense	74,778			71,926			204,713			196,487
Income tax expense	4,497			3,616			13,311			9,052
Net income	70,281			68,310			191,402			187,435
Less net income attributable to noncontrolling interest	123			—			143			—
Net income attributable to NuStar Energy L.P.	$	70,158		$	68,310		$	191,259		$	187,435
Net income per unit applicable to limited partners (Note 11)	$	0.92		$	0.90		$	2.49		$	2.55
Weighted-average limited partner units outstanding	64,612,423			64,610,549			64,611,181			62,386,373

See Condensed Notes to Consolidated Financial Statements.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited, Thousands of Dollars)



	Nine Months Ended September 30,
	2011			2010
Cash Flows from Operating Activities:
Net income	$	191,402		$	187,435
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	124,354			114,653
Amortization of debt related items	(8,328		)	(5,812		)
Gain on sale or disposition of assets, including insurance recoveries	(117		)	(12,926		)
Deferred income tax expense (benefit)	4,130			(1,932		)
Equity in earnings of joint venture	(6,997		)	(7,571		)
Distributions of equity in earnings of joint venture	9,397			7,500
Changes in current assets and current liabilities (Note 12)	(216,427		)	(99,815		)
Other, net	4,457			(699		)
Net cash provided by operating activities	101,871			180,833
Cash Flows from Investing Activities:
Reliability capital expenditures	(32,808		)	(34,927		)
Strategic capital expenditures	(211,150		)	(156,531		)
Acquisitions	(100,693		)	(43,026		)
Proceeds from insurance recoveries	—			13,500
Investment in other long-term assets	(8,449		)	(3,400		)
Proceeds from sale or disposition of assets	445			1,992
Net cash used in investing activities	(352,655		)	(222,392		)
Cash Flows from Financing Activities:
Proceeds from long-term debt borrowings	707,102			775,434
Proceeds from short-term debt borrowings	31,600			177,041
Proceeds from senior note offering, net of issuance costs	—			445,574
Long-term debt repayments	(348,153		)	(1,146,183		)
Short-term debt repayments	(31,600		)	(197,041		)
Proceeds from issuance of common units, net of issuance costs	1,583			240,158
Contributions from general partner	70			5,078
Distributions to unitholders and general partner	(240,571		)	(225,538		)
Proceeds from termination of interest rate swaps	12,632			—
Other, net	(785		)	(8,746		)
Net cash provided by financing activities	131,878			65,777
Effect of foreign exchange rate changes on cash	(3,001		)	(358		)
Net (decrease) increase in cash and cash equivalents	(121,907		)	23,860
Cash and cash equivalents as of the beginning of the period	181,121			62,006
Cash and cash equivalents as of the end of the period	$	59,214		$	85,866

See Condensed Notes to Consolidated Financial Statements.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. ORGANIZATION AND BASIS OF PRESENTATION

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 petroleum refining and marketing. Unless otherwise indicated, the terms “NuStar Energy,” “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) owns our general partner, Riverwalk Logistics, L.P., and owns a 17.6% total interest in us as of September 30, 2011.

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.

Basis of Presentation

These unaudited consolidated financial statements include the accounts of the Partnership and subsidiaries in which the Partnership has a controlling interest. Noncontrolling interests are separately disclosed on the consolidated balance sheets and consolidated statements of income. Intercompany balances and transactions have been eliminated in consolidation. We account for investments in 50% or less-owned entities using the equity method.

These unaudited consolidated financial statements have been prepared in accordance with United States generally accepted accounting principles (GAAP) for interim financial information and with the instructions to the Quarterly Report on Form 10-Q and Article 10 of Regulation S-X of the Securities Exchange Act of 1934. Accordingly, they do not include all of the information and notes required by GAAP for complete consolidated financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation have been included, and all disclosures are adequate. All such adjustments are of a normal recurring nature unless disclosed otherwise. Financial information for the three and nine months ended September 30, 2011 and 2010 included in these Condensed Notes to Consolidated Financial Statements is derived from our unaudited consolidated financial statements. Operating results for the three and nine months ended September 30, 2011 are not necessarily indicative of the results that may be expected for the year ending December 31, 2011. The consolidated balance sheet as of December 31, 2010 has been derived from the audited consolidated financial statements as of that date. These unaudited consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2010.

Reclassifications

Certain previously reported amounts in the 2010 consolidated financial statements have been reclassified to conform to the 2011 presentation.

Acquisitions

On April 19, 2011, we purchased certain refining and storage assets, inventory and other working capital items from AGE Refining, Inc. for $62.0 million, including the assumption of certain environmental liabilities. The assets consist of a 14,500 barrel per day refinery in San Antonio, Texas (the San Antonio Refinery) and 200,000 barrels of storage capacity in Elmendorf, Texas. The purchase price has been preliminarily 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. The consolidated statements of income include the results of operations for our acquisition of the San Antonio Refinery and related storage assets commencing on April 19, 2011.

On February 9, 2011, we acquired 75% of the outstanding capital of a Turkish company, which owns two terminals in Mersin, Turkey, with an aggregate 1.3 million barrels of storage capacity, for approximately $57.3 million (the Turkey Acquisition). Both terminals are connected via pipelines to an offshore platform located approximately three miles off the Mediterranean Sea coast. The purchase price has been preliminarily allocated based on the estimated fair values of the individual assets acquired, liabilities assumed and noncontrolling interest at the date of acquisition. The purchase price allocation is pending completion of an independent appraisal and other evaluations. The consolidated statements of income include the results of operations for the Turkey Acquisition commencing on February 9, 2011, with 25% accounted for as a noncontrolling interest.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

2. NEW ACCOUNTING PRONOUNCEMENTS

Goodwill Impairment

In September 2011, the Financial Accounting Standards Board (FASB) amended the goodwill impairment guidance to simplify testing goodwill for impairment. The amended guidance provides entities an option to first assess qualitative factors to determine whether it is necessary to perform the two-step quantitative goodwill impairment test. Under that option, an entity would not be required to calculate the fair value of a reporting unit unless the entity determines, based on that qualitative assessment, that it is more likely than not that its fair value is less than its carrying amount. The amended guidance is effective for annual and interim goodwill impairment tests performed for fiscal years beginning after December 15, 2011, and early adoption is permitted. We are evaluating whether to adopt the amended guidance for the 2011 goodwill impairment test performed in the fourth quarter, but we do not expect the amended guidance to have a material impact on our financial position or results of operations.

Other Comprehensive Income

In June 2011, the FASB amended the disclosure requirements for the presentation of comprehensive income. The amended requirements eliminate the option to present components of other comprehensive income (OCI) as part of the statement of changes in equity. Under the amended requirements, all changes in OCI are to be presented either in a single continuous statement of comprehensive income or in two separate but consecutive financial statements. In addition, entities will be required to disclose reclassification adjustments between other comprehensive income and net income separately on the face of the financial statements. The changes are effective for fiscal years and interim periods beginning after December 15, 2011, and retrospective application is required. Accordingly, we will adopt these provisions January 1, 2012. These amendments only affect financial statement presentation and will not have an impact on our financial position or results of operations.

Fair Value Measurements

In May 2011, the FASB issued amended guidance and disclosure requirements for fair value measurements. The new guidance results in a consistent definition of fair value and common requirements for measurement of and disclosure about fair value between GAAP and International Financial Reporting Standards. These changes are effective for interim and annual periods beginning on or after December 15, 2011, and early adoption is not permitted. Accordingly, we will adopt these provisions January 1, 2012, and we do not expect the amended guidance to have a material impact on our financial position, results of operations or disclosures.

3. INVENTORIES

Inventories consisted of the following:



	September 30, 2011		December 31, 2010
	(Thousands of Dollars)
Crude oil	$	220,672	$	122,945
Finished products	372,841		281,197
Materials and supplies	10,170		9,395
Total	$	603,683	$	413,537

4. DEBT

Revolving Credit Agreement

During the nine months ended September 30, 2011, we borrowed an aggregate $615.0 million under our $1.2 billion five-year revolving credit agreement (the 2007 Revolving Credit Agreement) to fund a portion of our capital expenditures and working capital requirements. Additionally, we repaid $348.2 million during the nine months ended September 30, 2011. The 2007 Revolving Credit Agreement bears interest based on either an alternative base rate or a LIBOR-based rate. As of September 30, 2011, our weighted average borrowing interest rate was 0.9%, and we had $376.2 million available for borrowing under the 2007 Revolving Credit Agreement. Due to a covenant in our 2007 Revolving Credit Agreement that requires us to maintain, as of the end of any four consecutive fiscal quarters, a consolidated debt coverage ratio not to exceed 5.00-to-1.00, we may not be able to borrow the maximum available amount. On March 7, 2011, we amended the 2007 Revolving Credit Agreement to exclude unused proceeds from the Gulf Opportunity Zone bond issuances from total indebtedness in the calculation of the

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

consolidated debt coverage ratio. As of September 30, 2011, our consolidated debt coverage ratio was 4.5x.

Gulf Opportunity Zone Revenue Bonds

The Parish of St. James, Louisiana issued, pursuant to the Gulf Opportunity Zone Act of 2005, three separate series of tax-exempt revenue bonds in 2010 and one series of tax-exempt revenue bonds in 2011 (GoZone Bonds) associated with our St. James terminal expansion. The $75.0 million of tax-exempt revenue bonds issued in 2011 mature on August 1, 2041. The interest rate on the GoZone Bonds is based on a weekly tax-exempt bond market interest rate, and interest is paid monthly. The interest rate was 0.2% as of September 30, 2011. 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 our St. James terminal expansion. The amount remaining in trust related to the GoZone Bonds is included in “Other long-term assets, net,” and the amount of bonds issued is included in “Long-term debt, less current portion” in our consolidated balance sheets. For the nine months ended September 30, 2011, $92.1 million was disbursed from the trustee. As of September 30, 2011, the amount remaining in trust totaled $187.6 million.

Lines of Credit

As of September 30, 2011, we had one short-term line of credit with an uncommitted borrowing capacity of up to $20.0 million. We had no outstanding borrowings on this line of credit as of September 30, 2011. During the nine months ended September 30, 2011, we borrowed and repaid $31.6 million related to this line of credit.

5. 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 September 30, 2011, we have accrued $76.5 million for contingent losses. The amount that will ultimately be paid related to these matters may differ from the amounts accrued, and the timing of such payments is uncertain.

Grace Energy Corporation Matter. In 1997, Grace Energy Corporation (Grace Energy) sued subsidiaries of Kaneb Pipeline Partners, L.P. (KPP) and Kaneb Services LLC (KSL and collectively with KPP and their respective subsidiaries, Kaneb) in Texas state court. We acquired Kaneb on July 1, 2005. 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.

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 United States 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, the proposed settlement must be approved by multiple parties and requires the approval of the bankruptcy court and the federal district court. We estimate that a settlement may be finalized in early to mid-2012.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

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 breached a tanker voyage charter party agreement, dated November 2004, between Eres and CARCO (the Charter Agreement). The Charter Agreement provided for CARCO's use of Eres' vessels for the shipment of asphalt. Eres contended 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 had failed to perform under the Charter Agreement. Eres valued its damages for the alleged breach of contract claim at approximately $78.1 million. On October 14, 2011, Eres and the Defendants entered into a Settlement Agreement and Mutual Release. Pursuant to the terms of the Settlement Agreement and Mutual Release, the NuStar Entities paid $33.5 million in full and final settlement of all of Eres' claims against the Defendants. The settlement amount was included in the accrual for contingent losses as of September 30, 2011.

Other. 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.

6. FAIR VALUE MEASUREMENTS

We segregate 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 consider counterparty credit risk and our own credit risk in the determination of all estimated fair values.

Product Imbalances

We value our assets and liabilities related to product imbalances using quoted market prices as of the reporting date.

Interest Rate Swaps

We estimate the fair value of both our fixed-to-floating and forward-starting interest rate swaps using discounted cash flows, which use observable inputs such as time to maturity and market interest rates.

Commodity Derivatives

The fair value of certain of our commodity derivative instruments are based on quoted prices on an exchange; accordingly, these are categorized in Level 1 of the fair value hierarchy. We also have derivative instruments that are are valued using industry pricing services and other observable inputs, such as quoted prices on an exchange for similar derivative instruments. Therefore, these derivative instruments are categorized in Level 2 of the fair value hierarchy. We have consistently applied these valuation techniques in all periods presented. See Note 7. Derivatives and Risk Management Activities for a discussion of our derivative instruments.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

The following assets and liabilities are measured at fair value:



	September 30, 2011
	Level 1			Level 2			Level 3		Total
	(Thousands of Dollars)
Other current assets:
Product imbalances	$	1,903		$	—		$	—	$	1,903
Commodity derivatives	22,534			—			—		22,534
Other long-term assets, net:
Interest rate swaps	—			23,125			—		23,125
Accrued liabilities:
Product imbalances	(1,069		)	—			—		(1,069		)
Commodity derivatives	(8,265		)	(50,433		)	—		(58,698		)
Interest rate swaps	—			(18,624		)	—		(18,624		)
Other long-term liabilities:
Interest rate swaps	—			(22,306		)	—		(22,306		)
Total	$	15,103		$	(68,238	)	$	—	$	(53,135	)



	December 31, 2010
	Level 1			Level 2			Level 3		Total
	(Thousands of Dollars)
Other current assets:
Product imbalances	$	991		$	—		$	—	$	991
Other long-term assets, net:
Interest rate swaps	—			45,663			—		45,663
Accrued liabilities:
Product imbalances	(988		)	—			—		(988		)
Commodity derivatives	(14,741		)	—			—		(14,741		)
Other long-term liabilities:
Interest rate swaps	—			(29,483		)	—		(29,483		)
Total	$	(14,738	)	$	16,180		$	—	$	1,442

Fair Value of Financial Instruments

We do not record our outstanding debt at fair value in our consolidated balance sheet. The estimated fair value and carrying amount of our debt was as follows:



	September 30, 2011		December 31, 2010
	(Thousands of Dollars)
Fair value	$	2,595,533	$	2,249,190
Carrying amount	$	2,525,655	$	2,137,080

We estimated the fair values of our debt using a discounted cash flow analysis using current incremental borrowing rates for similar types of borrowing arrangements.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

7. DERIVATIVES 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, futures and swaps 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 reviews all new commodity and trading risk management strategies in accordance with our risk management policy, as approved by our board of directors.

Interest Rate Risk

We are a party to certain interest rate swap agreements to manage our exposure to changes in interest rates. We have fixed-to-floating interest rate swap agreements associated with a portion of our fixed-rate senior notes. We account for our fixed-to-floating interest rate swaps as fair value hedges. During the nine months ended September 30, 2011, we entered into and terminated a fixed-to-floating interest rate swap agreement with a notional amount of $40.0 million related to the 7.65% senior notes issued in April 2008. We also terminated interest rate swap agreements with an aggregate notional amount of $167.5 million associated with our 6.875% and 6.05% senior notes during the nine months ended September 30, 2011. We received $12.6 million in connection with the terminations, which is being amortized into "Interest expense, net" over the remaining lives of the 7.65%, 6.875% and 6.05% senior notes. Proceeds from the termination of interest rate swap agreements are included in cash flows from financing activities on the consolidated statements of cash flows.

The total aggregate notional amount of the fixed-to-floating interest rate swaps was $450.0 million as of September 30, 2011 and $617.5 million as of December 31, 2010. The weighted-average interest rate that we paid under our fixed-to-floating interest rate swaps was 2.6% as of September 30, 2011.

We are also a party to forward-starting interest rate swap agreements with an aggregate notional amount of $500.0 million as of September 30, 2011 and December 31, 2010 related to forecasted probable debt issuances in 2012 and 2013. We entered into the swaps in order to hedge the risk of changes in the interest payments attributable to changes in the benchmark interest rate during the period from the effective date of the swap to the issuance of the forecasted debt. These swaps are designated and qualify as cash flow hedges.

Commodity Price Risk

We are exposed to market risks related to the volatility of crude oil and refined product prices. In order to reduce the risk of commodity price fluctuations with respect to our crude oil and finished product inventories and related firm commitments to purchase and/or sell such inventories, we utilize commodity futures and swap contracts, which qualify and we designate as fair value hedges.

During the second quarter of 2011, we entered into commodity swap contracts to hedge the price risk associated with the San Antonio Refinery. These contracts fix the purchase price of crude oil and sales prices of refined products for a portion of the expected production of the San Antonio Refinery, thereby attempting to mitigate the risk of volatility of future cash flows associated with hedged volumes. These contracts qualified and we designated them as cash flow hedges.

Derivatives that are intended to hedge our commodity price risk, but fail to qualify as fair value or cash flow hedges, are considered economic hedges, and associated gains and losses are recorded in net income. We also enter into commodity derivatives 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. Changes in the fair values are recorded in net income.

The volume of commodity contracts is based on open derivative positions and represents the combined volume of our long and short positions on an absolute basis, which totaled 31.2 million barrels and 12.8 million barrels as of September 30, 2011 and December 31, 2010, respectively.

As of December 31, 2010, we had $17.8 million of margin deposits related to our derivative instruments and none as of September 30, 2011.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

The fair values of our derivative instruments included in our consolidated balance sheets were as follows:



		Asset Derivatives				Liability Derivatives
	Balance Sheet Location	September 30, 2011		December 31, 2010		September 30, 2011			December 31, 2010
		(Thousands of Dollars)
Derivatives Designated as Hedging Instruments:
Commodity contracts	Other current assets	$	3,072	$	—	$	(72	)	$	—
Interest rate swaps	Other long-term assets, net	23,125		45,663		—			—
Commodity contracts	Accrued liabilities	196,026		2,176		(246,459		)	(2,522		)
Interest rate swaps	Accrued liabilities	—		—		(18,624		)	—
Interest rate swaps	Other long-term liabilities	—		—		(22,306		)	(29,483		)
Total		222,223		47,839		(287,461		)	(32,005		)

Derivatives Not Designated as Hedging Instruments:
Commodity contracts	Other current assets	38,774		—		(19,240		)	—
Commodity contracts	Accrued liabilities	10,826		46,632		(19,091		)	(61,027		)
Total		49,600		46,632		(38,331		)	(61,027		)

Total Derivatives		$	271,823	$	94,471	$	(325,792	)	$	(93,032	)

The earnings impact of our derivative activity was as follows:



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)
Three months ended September 30, 2011:
Interest rate swaps	Interest expense, net	$	45,963		$	(46,320	)	$	(357	)
Commodity contracts	Cost of product sales	3,772			(4,508		)	(736		)
Total		$	49,735		$	(50,828	)	$	(1,093	)

Three months ended September 30, 2010:
Interest rate swaps	Interest expense, net	$	3,886		$	(3,886	)	$	—
Commodity contracts	Cost of product sales	(6,773		)	12,297			5,524
Total		$	(2,887	)	$	8,411		$	5,524

Nine months ended September 30, 2011:
Interest rate swaps	Interest expense, net	$	54,577		$	(55,172	)	$	(595	)
Commodity contracts	Cost of product sales	(7,292		)	6,212			(1,080		)
Total		$	47,285		$	(48,960	)	$	(1,675	)

Nine months ended September 30, 2010:
Interest rate swaps	Interest expense, net	$	7,010		$	(7,010	)	$	—
Commodity contracts	Cost of product sales	4,961			3,382			8,343
Total		$	11,971		$	(3,628	)	$	8,343

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)



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)
Three months ended September 30, 2011:
Interest rate swaps	$	(63,100	)	Interest expense, net	$	—		$	—
Commodity contracts	(46,532		)	Cost of product sales	(7,733		)	3,594
Total	$	(109,632	)		$	(7,733	)	$	3,594

Three months ended September 30, 2010:
Interest rate swaps	$	(1,790	)	Interest expense, net	$	—		$	—
Commodity contracts	(1,326		)	Cost of product sales	—			(284		)
Total	$	(3,116	)		$	—		$	(284	)

Nine months ended September 30, 2011:
Interest rate swaps	$	(75,930	)	Interest expense, net	$	—		$	—
Commodity contracts	(62,986		)	Cost of product sales	(8,958		)	3,594
Total	$	(138,916	)		$	(8,958	)	$	3,594

Nine months ended September 30, 2010:
Interest rate swaps	$	(1,790	)	Interest expense, net	$	—		$	—
Commodity contracts	(1,087		)	Cost of product sales	(913		)	—
Total	$	(2,877	)		$	(913	)	$	—


(a)	Amounts are included in specified location for both the gain (loss) reclassified from accumulated other comprehensive income 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)
Three months ended September 30, 2011:
Commodity contracts	Cost of product sales	$	5,482

Three months ended September 30, 2010:
Commodity contracts	Cost of product sales	$	(1,963	)

Nine months ended September 30, 2011:
Commodity contracts	Revenues	$	235
Commodity contracts	Cost of product sales	(5,685		)
Commodity contracts	Operating expenses	46
Total		$	(5,404	)

Nine months ended September 30, 2010:
Commodity contracts	Cost of product sales	$	4,735
Commodity contracts	Operating expenses	(10		)
Total		$	4,725

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

For derivatives designated as cash flow hedging instruments, once a hedged transaction occurs, we reclassify the effective portion from accumulated OCI to “Cost of product sales” or “Interest expense, net.” As of September 30, 2011, we expect to reclassify a loss of $25.0 million to “Cost of product sales” and a loss of $1.2 million to “Interest expense, net” within the next twelve months. The maximum length of time over which we are hedging our exposure to the variability in future cash flows is approximately two years for our forward-starting interest rate swaps and approximately four years for our commodity contracts.

8. RELATED PARTY TRANSACTIONS

Our operations are managed by NuStar GP, LLC, the general partner of our general partner. Under a services agreement between NuStar Energy and NuStar GP, LLC, 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. Employees of NuStar GP, LLC provide services to both NuStar Energy and NuStar GP Holdings; therefore, we reimburse NuStar GP, LLC for all costs related to its employees, other than costs associated with NuStar GP Holdings. Related party revenues result from storage agreements between our Turkey subsidiary and the noncontrolling shareholder.



The following table summarizes information pertaining to related party transactions:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2011		2010		2011		2010
	(Thousands of Dollars)
Revenues	$	286	$	—	$	823	$	—
Operating expenses	$	37,151	$	35,644	$	109,061	$	103,563
General and administrative expenses	$	8,985	$	17,133	$	41,968	$	47,691

We had a payable to NuStar GP, LLC of $12.4 million and $10.3 million, as of September 30, 2011 and December 31, 2010, respectively, with both amounts representing payroll, employee benefit plans and unit-based compensation. We also had a long-term payable to NuStar GP, LLC as of September 30, 2011 and December 31, 2010 of $11.9 million and $10.1 million, respectively, related to amounts payable for retiree medical benefits and other post-employment benefits.

9. OTHER INCOME (EXPENSE)

Other income (expense), net consisted of the following:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2011			2010			2011			2010
	(Thousands of Dollars)
Contingent loss adjustment	$	(3,250	)	$	—		$	(3,250	)	$	—
Storage agreement early termination costs	—			—			(5,000		)	—
Gain from insurance recoveries	—			—			—			13,500
(Loss) gain from sale or disposition of assets	(119		)	114			117			(574		)
Foreign exchange gains (losses)	3,059			(333		)	2,483			(567		)
Other, net	1,077			(16		)	(49		)	2,523
Other income (expense), net	$	767		$	(235	)	$	(5,699	)	$	14,882

For the three and nine months ended September 30, 2011, the contingent loss adjustment relates to the Eres matter discussed in Note 5. Commitments and Contingencies. For the nine months ended September 30, 2011, "Other income (expense), net" included $5.0 million in costs associated with the early termination of a third-party storage agreement at our Paulsboro, New Jersey asphalt refinery. For the nine months ended September 30, 2010, the gain from insurance recoveries resulted from insurance claims related to damage in the third quarter of 2008 primarily at our Texas City, Texas terminal caused by Hurricane Ike.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

10. PARTNERS’ EQUITY

Partners' Equity Activity

The following table summarizes changes in the carrying amount of partners' equity and noncontrolling interest:



	Three Months Ended September 30, 2011									Three Months Ended September 30, 2010
	NuStar Energy L.P. Partners' Equity			Noncontrolling Interest			Total Partners' Equity			NuStar Energy L.P. Partners' Equity			Noncontrolling Interest		Total Partners' Equity
	(Thousands of Dollars)
Beginning balance	$	2,644,221		$	14,745		$	2,658,966		$	2,694,908		$	—	$	2,694,908
Net income	70,158			123			70,281			68,310			—		68,310
Other comprehensive income:
Foreign currency translation adjustment	(22,165		)	(2,186		)	(24,351		)	9,026			—		9,026
Unrealized gain (loss) on cash flow hedges	(109,632		)	—			(109,632		)	(3,116		)	—		(3,116		)
Net loss reclassified into income on cash flow hedges	7,733			—			7,733			—			—		—
Total other comprehensive (loss) income	(124,064		)	(2,186		)	(126,250		)	5,910			—		5,910
Total comprehensive (loss) income	(53,906		)	(2,063		)	(55,969		)	74,220			—		74,220
Cash distributions to partners	(81,339		)	—			(81,339		)	(78,754		)	—		(78,754		)
Issuance of common units, including contribution from general partner	3,391			—			3,391			(139		)	—		(139		)
Ending balance	$	2,512,367		$	12,682		$	2,525,049		$	2,690,235		$	—	$	2,690,235

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)



	Nine Months Ended September 30, 2011									Nine Months Ended September 30, 2010
	NuStar Energy L.P. Partners' Equity			Noncontrolling Interest			Total Partners' Equity			NuStar Energy L.P. Partners' Equity			Noncontrolling Interest		Total Partners' Equity
	(Thousands of Dollars)
Beginning balance	$	2,702,700		$	—		$	2,702,700		$	2,484,968		$	—	$	2,484,968
Turkey acquisition	—			15,000			15,000			—					—
Net income	191,259			143			191,402			187,435			—		187,435
Other comprehensive income:
Foreign currency translation adjustment	(14,454		)	(2,461		)	(16,915		)	98			—		98
Unrealized gain (loss) on cash flow hedges	(138,916		)	—			(138,916		)	(2,877		)	—		(2,877		)
Net loss reclassified into income on cash flow hedges	8,958			—			8,958			913			—		913
Total other comprehensive (loss)	(144,412		)	(2,461		)	(146,873		)	(1,866		)	—		(1,866		)
Total comprehensive income (loss)	46,847			(2,318		)	44,529			185,569			—		185,569
Cash distributions to partners	(240,571		)	—			(240,571		)	(225,538		)	—		(225,538		)
Issuance of common units, including contribution from general partner	3,391			—			3,391			245,236			—		245,236
Ending balance	$	2,512,367		$	12,682		$	2,525,049		$	2,690,235		$	—	$	2,690,235

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 and the general partner will receive. The partnership agreement also contains provisions for the allocation of net income and loss to the unitholders and the general partner. For purposes of maintaining partner 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 made after giving effect to priority income allocations, if any, in an amount equal to incentive cash distributions allocated 100% to the general partner. The following table details the calculation of net income applicable to the general partner:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2011			2010			2011			2010
	(Thousands of Dollars)
Net income attributable to NuStar Energy L.P.	$	70,158		$	68,310		$	191,259		$	187,435
Less general partner incentive distribution	8,972			8,568			26,503			24,736
Net income after general partner incentive distribution	61,186			59,742			164,756			162,699
General partner interest	2		%	2		%	2		%	2		%
General partner allocation of net income after general partner incentive distribution	1,223			1,195			3,294			3,254
General partner incentive distribution	8,972			8,568			26,503			24,736
Net income applicable to general partner	$	10,195		$	9,763		$	29,797		$	27,990

Cash Distributions

On August 12, 2011, we paid a quarterly cash distribution totaling $81.3 million, or $1.095 per unit, related to the second quarter of 2011. On October 28, 2011, we announced a quarterly cash distribution of $1.095 per unit related to the third quarter of 2011. This distribution will be paid on November 14, 2011 to unitholders of record on November 8, 2011 and will total $81.4 million.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

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



	Three Months Ended September 30,				Nine Months Ended September 30,
	2011		2010		2011		2010
	(Thousands of Dollars, Except Per Unit Data)
General partner interest	$	1,628	$	1,592	$	4,847	$	4,635
General partner incentive distribution	8,972		8,568		26,503		24,736
Total general partner distribution	10,600		10,160		31,350		29,371
Limited partners’ distribution	70,814		69,456		211,019		202,391
Total cash distributions	$	81,414	$	79,616	$	242,369	$	231,762

Cash distributions per unit applicable to limited partners	$	1.095	$	1.075	$	3.265	$	3.205

11. NET INCOME PER UNIT

We have identified the general partner interest and incentive 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 units outstanding during the period. Basic and diluted net income per unit applicable to limited partners are the same because we have no potentially dilutive securities outstanding.

The following table details the calculation of earnings per unit:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2011			2010			2011			2010
	(Thousands of Dollars, Except Unit and Per Unit Data)
Net income attributable to NuStar Energy L.P.	$	70,158		$	68,310		$	191,259		$	187,435
Less general partner distribution (including IDR)	10,600			10,160			31,350			29,371
Less limited partner distribution	70,814			69,456			211,019			202,391
Distributions greater than earnings	$	(11,256	)	$	(11,306	)	$	(51,110	)	$	(44,327	)

General partner earnings:
Distributions	$	10,600		$	10,160		$	31,350		$	29,371
Allocation of distributions greater than earnings (2%)	(225		)	(225		)	(1,023		)	(886		)
Total	$	10,375		$	9,935		$	30,327		$	28,485

Limited partner earnings:
Distributions	$	70,814		$	69,456		$	211,019		$	202,391
Allocation of distributions greater than earnings (98%)	(11,031		)	(11,081		)	(50,087		)	(43,441		)
Total	$	59,783		$	58,375		$	160,932		$	158,950

Weighted-average limited partner units outstanding	64,612,423			64,610,549			64,611,181			62,386,373

Net income per unit applicable to limited partners	$	0.92		$	0.90		$	2.49		$	2.55

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

12. STATEMENTS OF CASH FLOWS

Changes in current assets and current liabilities were as follows:



	Nine Months Ended September 30,
	2011			2010
	(Thousands of Dollars)
Decrease (increase) in current assets:
Accounts receivable	$	(148,814	)	$	(86,025	)
Inventories	(176,936		)	(114,885		)
Other current assets	(25,838		)	27,287
Increase (decrease) in current liabilities:
Accounts payable	153,626			75,345
Payable to related party	2,023			12,697
Accrued interest payable	(6,092		)	3,058
Accrued liabilities	(21,471		)	(18,436		)
Taxes other than income tax	5,607			(858		)
Income tax payable	1,468			2,002
Changes in current assets and current liabilities	$	(216,427	)	$	(99,815	)

Cash flows related to interest and income taxes were as follows:



	Nine Months Ended September 30,
	2011		2010
	(Thousands of Dollars)
Cash paid for interest, net of amount capitalized	$	87,576	$	66,243
Cash paid for income taxes, net of tax refunds received	$	11,974	$	9,580

13. SEGMENT INFORMATION

Our reportable business segments consist of storage, transportation, and asphalt and fuels marketing. Our segments represent strategic business units that offer different services and products. We evaluate the performance of each segment based on its respective operating income, before general and administrative 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. Our principal operations include terminalling and storage of petroleum products, the transportation of petroleum products and anhydrous ammonia, and petroleum refining and marketing. Intersegment revenues result from storage and throughput agreements with related parties at lease rates consistent with rates charged to third parties for storage and at pipeline tariff rates based upon the applicable published tariff.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Results of operations for the reportable segments were as follows:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2011			2010			2011			2010
	(Thousands of Dollars)
Revenues:
Storage:
Third parties	$	128,561		$	120,793		$	381,460		$	353,337
Intersegment	13,042			10,344			35,925			33,241
Related party	286			—			823			—
Total storage	141,889			131,137			418,208			386,578
Transportation:
Third parties	81,834			80,597			226,406			232,435
Intersegment	65			—			65			382
Total transportation	81,899			80,597			226,471			232,817
Asphalt and fuels marketing:
Third parties	1,613,669			936,989			4,039,461			2,623,077
Intersegment	5,024			85			9,618			2,917
Total asphalt and fuels marketing	1,618,693			937,074			4,049,079			2,625,994
Consolidation and intersegment eliminations	(18,131		)	(10,429		)	(45,608		)	(36,540		)
Total revenues	$	1,824,350		$	1,138,379		$	4,648,150		$	3,208,849

Operating income:
Storage	$	48,778		$	45,635		$	140,322		$	131,388
Transportation	38,248			37,512			102,808			106,004
Asphalt and fuels marketing	25,418			35,457			97,689			75,113
Consolidation and intersegment eliminations	29			1			(16		)	278
Total segment operating income	112,473			118,605			340,803			312,783
Less general and administrative expenses	17,731			26,860			69,833			76,324
Less other depreciation and amortization expense	1,765			1,455			4,911			4,366
Total operating income	$	92,977		$	90,290		$	266,059		$	232,093

Total assets by reportable segment were as follows:



	September 30, 2011		December 31, 2010
	(Thousands of Dollars)
Storage	$	2,556,356	$	2,454,264
Transportation	1,251,463		1,256,614
Asphalt and fuels marketing	1,655,442		1,154,499
Total segment assets	5,463,261		4,865,377
Other partnership assets	384,887		521,016
Total consolidated assets	$	5,848,148	$	5,386,393

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

14. 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 each of 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 presented as an alternative to providing separate financial statements for NuStar Logistics and NuPOP.

Condensed Consolidating Balance Sheets

September 30, 2011

(Thousands of Dollars)



	NuStar Energy		NuStar Logistics		NuPOP		Non-Guarantor Subsidiaries (a)		Eliminations			Consolidated
Assets
Cash and cash equivalents	$	122	$	6	$	—	$	59,086	$	—		$	59,214
Receivables, net	1,738		17,781		12,425		435,968		—			467,912
Inventories	—		2,277		14,686		586,969		(249		)	603,683
Other current assets	—		13,429		2,378		53,294		—			69,101
Intercompany receivable	—		853,945		745,079		—		(1,599,024		)	—
Total current assets	1,860		887,438		774,568		1,135,317		(1,599,273		)	1,199,910
Property, plant and equipment, net	—		1,119,814		599,770		1,665,852		—			3,385,436
Intangible assets, net	—		2,001		—		40,498		—			42,499
Goodwill	—		18,094		170,652		657,780		—			846,526
Investment in wholly owned subsidiaries	3,119,736		249,458		1,137,467		2,315,991		(6,822,652		)	—
Investment in joint venture	—		—		—		67,203		—			67,203
Deferred income tax asset	—		—		—		9,671		—			9,671
Other long-term assets, net	217		227,657		26,329		42,700		—			296,903
Total assets	$	3,121,813	$	2,504,462	$	2,708,786	$	5,935,012	$	(8,421,925	)	$	5,848,148
Liabilities and Partners’ Equity
Current portion of long-term debt	$	—	$	102,510	$	253,135	$	—	$	—		$	355,645
Payables	63		35,459		7,953		429,932		—			473,407
Accrued interest payable	—		16,273		7,318		24		—			23,615
Accrued liabilities	755		30,857		3,925		75,397		—			110,934
Taxes other than income tax	63		4,812		3,586		8,038		—			16,499
Income tax payable	—		1,462		—		1,497		—			2,959
Intercompany payable	510,653		—		—		1,088,371		(1,599,024		)	—
Total current liabilities	511,534		191,373		275,917		1,603,259		(1,599,024		)	983,059
Long-term debt, less current portion	—		1,883,485		253,709		32,816		—			2,170,010
Long-term payable to related party	—		5,390		—		6,481		—			11,871
Deferred income tax liability	—		—		—		35,917		—			35,917
Other long-term liabilities	—		25,299		245		96,698		—			122,242
Total partners' equity	2,610,279		398,915		2,178,915		4,159,841		(6,822,901		)	2,525,049
Total liabilities and partners’ equity	$	3,121,813	$	2,504,462	$	2,708,786	$	5,935,012	$	(8,421,925	)	$	5,848,148


(a)	Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Condensed Consolidating Balance Sheets

December 31, 2010

(Thousands of Dollars)



	NuStar Energy		NuStar Logistics		NuPOP		Non-Guarantor Subsidiaries (a)		Eliminations			Consolidated
Assets
Cash and cash equivalents	$	53	$	107,655	$	—	$	73,413	$	—		$	181,121
Receivables, net	—		27,708		10,648		266,885		(3,188		)	302,053
Inventories	—		1,776		6,712		405,521		(472		)	413,537
Other current assets	—		10,116		1,202		31,478		—			42,796
Intercompany receivable	—		786,658		729,365		—		(1,516,023		)	—
Total current assets	53		933,913		747,927		777,297		(1,519,683		)	939,507
Property, plant and equipment, net	—		1,006,479		614,762		1,566,216		—			3,187,457
Intangible assets, net	—		2,106		—		40,927		—			43,033
Goodwill	—		18,094		170,652		624,524		—			813,270
Investment in wholly owned subsidiaries	3,167,764		159,813		994,249		2,112,355		(6,434,181		)	—
Investment in joint venture	—		—		—		69,603		—			69,603
Deferred income tax asset	—		—		—		8,138		—			8,138
Other long-term assets, net	—		267,532		26,329		31,524		—			325,385
Total assets	$	3,167,817	$	2,387,937	$	2,553,919	$	5,230,584	$	(7,953,864	)	$	5,386,393
Liabilities and Partners’ Equity
Current portion of long-term debt	$	—	$	832	$	—	$	—	$	—		$	832
Payables	—		28,705		9,559		257,651		(3,188		)	292,727
Accrued interest payable	—		21,180		8,490		36		—			29,706
Accrued liabilities	680		18,154		3,973		35,146		—			57,953
Taxes other than income tax	125		4,273		2,587		3,733		—			10,718
Income tax payable	—		1,140		—		153		—			1,293
Intercompany payable	510,812		—		—		1,005,211		(1,516,023		)	—
Total current liabilities	511,617		74,284		24,609		1,301,930		(1,519,211		)	393,229
Long-term debt, less current portion	—		1,589,189		514,270		32,789		—			2,136,248
Long-term payable to related party	—		3,571		—		6,517		—			10,088
Deferred income tax liability	—		—		—		29,565		—			29,565
Other long-term liabilities	—		33,458		228		80,877		—			114,563
Total partners’ equity	2,656,200		687,435		2,014,812		3,778,906		(6,434,653		)	2,702,700
Total liabilities and partners’ equity	$	3,167,817	$	2,387,937	$	2,553,919	$	5,230,584	$	(7,953,864	)	$	5,386,393


(a)	Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Condensed Consolidating Statements of Income

For the Three Months Ended September 30, 2011

(Thousands of Dollars)



	NuStar Energy			NuStar Logistics			NuPOP			Non-Guarantor Subsidiaries (a)			Eliminations			Consolidated
Revenues	$	—		$	78,554		$	46,076		$	1,708,288		$	(8,568	)	$	1,824,350
Costs and expenses	482			38,068			32,090			1,669,422			(8,689		)	1,731,373
Operating (loss) income	(482		)	40,486			13,986			38,866			121			92,977
Equity in earnings of subsidiaries	70,641			7,285			29,828			51,102			(158,856		)	—
Equity in earnings of joint venture	—			—			—			2,599			—			2,599
Interest expense, net	—			(15,210		)	(5,685		)	(670		)	—			(21,565		)
Other income, net	—			109			246			412			—			767
Income (loss) before income tax expense	70,159			32,670			38,375			92,309			(158,735		)	74,778
Income tax expense	1			542			—			3,954			—			4,497
Net income (loss)	70,158			32,128			38,375			88,355			(158,735		)	70,281
Less net income attributable to noncontrolling interest	—			—			—			123			—			123
Net income (loss) attributable to NuStar Energy L.P.	$	70,158		$	32,128		$	38,375		$	88,232		$	(158,735	)	$	70,158


(a)	Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

Table of Contents

NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Condensed Consolidating Statements of Income

For the Three Months Ended September 30, 2010

(Thousands of Dollars)



	NuStar Energy			NuStar Logistics			NuPOP			Non-Guarantor Subsidiaries (a)			Eliminations			Consolidated
Revenues	$	—		$	72,051		$	44,675		$	1,025,036		$	(3,383	)	$	1,138,379
Costs and expenses	367			46,664			31,267			973,091			(3,300		)	1,048,089
Operating (loss) income	(367		)	25,387			13,408			51,945			(83		)	90,290
Equity in earnings of subsidiaries	68,677			24,837			25,808			39,563			(158,885		)	—
Equity in earnings of joint venture	—			—			—			2,454			—			2,454
Interest expense, net	—			(14,330		)	(5,827		)	(426		)	—			(20,583		)
Other income, net	—			69			(16		)	(288		)	—			(235		)
Income (loss) before income tax expense	68,310			35,963			33,373			93,248			(158,968		)	71,926
Income tax expense	—			465			—			3,151			—			3,616
Net income (loss)	$	68,310		$	35,498		$	33,373		$	90,097		$	(158,968	)	$	68,310


(a)	Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Condensed Consolidating Statements of Income

For the Nine Months Ended September 30, 2011

(Thousands of Dollars)



	NuStar Energy			NuStar Logistics			NuPOP			Non-Guarantor Subsidiaries (a)			Eliminations			Consolidated
Revenues	$	—		$	212,483		$	136,525		$	4,325,226		$	(26,084	)	$	4,648,150
Costs and expenses	1,283			124,399			98,669			4,184,028			(26,288		)	4,382,091
Operating (loss) income	(1,283		)	88,084			37,856			141,198			204			266,059
Equity in earnings of subsidiaries	192,543			41,827			86,491			146,940			(467,801		)	—
Equity in earnings of joint venture	—			—			—			6,997			—			6,997
Interest expense, net	—			(43,234		)	(17,236		)	(2,174		)	—			(62,644		)
Other income, net	—			292			265			(6,256		)	—			(5,699		)
Income (loss) before income tax expense	191,260			86,969			107,376			286,705			(467,597		)	204,713
Income tax expense	1			1,569			—			11,741			—			13,311
Net income (loss)	191,259			85,400			107,376			274,964			(467,597		)	191,402
Less net income attributable to noncontrolling interest	—			—			—			143			—			143
Net income (loss) attributable to NuStar Energy L.P.	$	191,259		$	85,400		$	107,376		$	274,821		$	(467,597	)	$	191,259


(a)	Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

Table of Contents

NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Condensed Consolidating Statements of Income

For the Nine Months Ended September 30, 2010

(Thousands of Dollars)



	NuStar Energy			NuStar Logistics			NuPOP			Non-Guarantor Subsidiaries (a)			Eliminations			Consolidated
Revenues	$	—		$	219,277		$	117,535		$	2,888,095		$	(16,058	)	$	3,208,849
Costs and expenses	1,042			139,698			87,245			2,766,926			(18,155		)	2,976,756
Operating (loss) income	(1,042		)	79,579			30,290			121,169			2,097			232,093
Equity in earnings of subsidiaries	188,476			39,295			93,698			134,457			(455,926		)	—
Equity in earnings of joint venture	—			—			—			7,571			—			7,571
Interest expense, net	1			(38,744		)	(17,671		)	(1,645		)	—			(58,059		)
Other income, net	—			1,308			243			13,331			—			14,882
Income (loss) before income tax expense	187,435			81,438			106,560			274,883			(453,829		)	196,487
Income tax expense	—			1,191			—			7,861			—			9,052
Net income (loss)	$	187,435		$	80,247		$	106,560		$	267,022		$	(453,829	)	$	187,435


(a)	Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Condensed Consolidating Statements of Cash Flows

For the Nine Months Ended September 30, 2011

(Thousands of Dollars)



	NuStar Energy			NuStar Logistics			NuPOP			Non-Guarantor Subsidiaries (a)			Eliminations			Consolidated
Net cash provided by (used in) operating activities	$	239,146		$	84,681		$	20,883		$	(2,244	)	$	(240,595	)	$	101,871
Cash flows from investing activities:
Capital expenditures	—			(152,764		)	(4,954		)	(86,240		)	—			(243,958		)
Acquisitions	—			—			—			(100,693		)	—			(100,693		)
Investment in other long-term assets	—			—			—			(8,449		)	—			(8,449		)
Proceeds from sale or disposition of assets	—			57			79			309			—			445
Investment in subsidiaries	(57,300		)	(47,820		)	(56,727		)	(56,727		)	218,574			—
Net cash used in investing activities	(57,300		)	(200,527		)	(61,602		)	(251,800		)	218,574			(352,655		)
Cash flows from financing activities:
Debt borrowings	—			738,702			—			—			—			738,702
Debt repayments	—			(379,753		)	—			—			—			(379,753		)
Issuance of common units, net of issuance costs	1,583			—			—			—			—			1,583
General partner contribution	70			—			—			—			—			70
Distributions to unitholders and general partner	(240,571		)	(240,571		)	—			(24		)	240,595			(240,571		)
Contributions from (distributions to) affiliates	57,300			(57,300		)	56,727			161,847			(218,574		)	—
Proceeds from termination of interest rate swaps	—			12,632			—			—			—			12,632
Net intercompany borrowings (repayments)	(159		)	(66,833		)	(16,008		)	83,000			—			—
Other, net	—			181			—			(966		)	—			(785		)
Net cash provided by (used in) financing activities	(181,777		)	7,058			40,719			243,857			22,021			131,878
Effect of foreign exchange rate changes on cash	—			1,139			—			(4,140		)	—			(3,001		)
Net (decrease) increase in cash and cash equivalents	69			(107,649		)	—			(14,327		)	—			(121,907		)
Cash and cash equivalents as of the beginning of the period	53			107,655			—			73,413			—			181,121
Cash and cash equivalents as of the end of the period	$	122		$	6		$	—		$	59,086		$	—		$	59,214


(a)	Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Condensed Consolidating Statements of Cash Flows

For the Nine Months Ended September 30, 2010

(Thousands of Dollars)



	NuStar Energy			NuStar Logistics			NuPOP			Non-Guarantor Subsidiaries (a)			Eliminations			Consolidated
Net cash provided by (used in) operating activities	$	223,178		$	122,613		$	14,937		$	45,666		$	(225,561	)	$	180,833
Cash flows from investing activities:
Capital expenditures	—			(75,175		)	(10,017		)	(106,266		)	—			(191,458		)
Acquisition	—			—			—			(43,026		)	—			(43,026		)
Proceeds from insurance recoveries	—			—			—			13,500			—			13,500
Investment in other long-term assets	—			—			—			(3,400		)	—			(3,400		)
Proceeds from sale or disposition of assets	—			16			28			1,948			—			1,992
Investment in subsidiaries	(245,604		)	—			—			(25		)	245,629			—
Net cash used in investing activities	(245,604		)	(75,159		)	(9,989		)	(137,269		)	245,629			(222,392		)
Cash flows from financing activities:
Debt borrowings	—			952,475			—			—			—			952,475
Debt repayments	—			(1,343,224		)	—			—			—			(1,343,224		)
Senior note offering, net	—			445,574			—			—			—			445,574
Issuance of common units, net of issuance costs	240,158			—			—			—			—			240,158
General partner contribution	5,078			—			—			—			—			5,078
Contributions from (distributions to) affiliates	—			245,604			—			25			(245,629		)	—
Distributions to unitholders and general partner	(225,538		)	(225,538		)	—			(23		)	225,561			(225,538		)
Net intercompany borrowings (repayments)	2,728			(90,801		)	(4,947		)	93,020			—			—
Other, net	—			(6,987		)	(1		)	(1,758		)	—			(8,746		)
Net cash provided by (used in) financing activities	22,426			(22,897		)	(4,948		)	91,264			(20,068		)	65,777
Effect of foreign exchange rate changes on cash	—			(5,290		)	—			4,932			—			(358		)
Net decrease in cash and cash equivalents	—			19,267			—			4,593			—			23,860
Cash and cash equivalents as of the beginning of the period	53			1,602			—			60,351			—			62,006
Cash and cash equivalents as of the end of the period	$	53		$	20,869		$	—		$	64,944		$	—		$	85,866


(a)	Non-guarantor subsidiaries are wholly owned by NuStar Energy, NuStar Logistics or NuPOP.

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

FORWARD-LOOKING STATEMENTS

This Form 10-Q 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,” “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 our Annual Report on Form 10-K for the year ended December 31, 2010, Part I, Item 1A “Risk Factors,” as well as our subsequent current and quarterly reports, for a discussion of certain of those risks, uncertainties and assumptions.

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 this Form 10-Q. 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) is a publicly held Delaware limited partnership engaged in the terminalling and storage of petroleum products, the transportation of petroleum products and anhydrous ammonia, and petroleum refining and marketing. Unless otherwise indicated, the terms “NuStar Energy,” “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) owns our general partner, Riverwalk Logistics, L.P., and owns a 17.6% total interest in us as of September 30, 2011. Our Management’s Discussion and Analysis of Financial Condition and Results of Operations is presented in six sections:


•	Overview


•	Results of Operations


•	Outlook


•	Liquidity and Capital Resources


•	Related Party Transactions


•	Critical Accounting Policies

Acquisitions

Operations

We conduct our operations through our subsidiaries, primarily NuStar Logistics, L.P. (NuStar Logistics) and NuStar Pipeline Operating Partnership L.P. (NuPOP). Our operations are divided into three reportable business segments: storage, transportation, and asphalt and fuels marketing.

Storage. We own terminals and storage facilities in the United States, Canada, Mexico, the Netherlands, including St. Eustatius in the Caribbean, the United Kingdom and Turkey providing approximately 85.0 million barrels of storage capacity. Our terminals and storage facilities provide storage and handling services on a fee basis for petroleum products, specialty chemicals and other liquids, including crude oil and other feedstocks.

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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 5,478 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 939 miles of crude oil pipelines in Texas, Oklahoma, Kansas, Colorado and Illinois, as well as 1.9 million barrels of crude storage in Texas and Oklahoma that is located along those 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 refining operations and fuels marketing operations. We refine crude oil to produce asphalt and other refined products from our asphalt operations. Our two asphalt refineries have a combined throughput capacity of 104,000 barrels per day, and the related terminal facilities provide storage capacity of 5.0 million barrels. This segment also include a fuels refinery in San Antonio, Texas with throughput capacity of 14,500 barrels per day. Additionally, as part of our fuels marketing operations, we purchase crude oil and refined petroleum products for resale. The results of operations for the asphalt and fuels marketing segment depend largely on the gross margin between our costs 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 our storage and transportation segments. We enter into derivative contracts to attempt to mitigate the effect of commodity price fluctuations.

The following factors affect the results of our operations:


•	company-specific factors, such as facility 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; 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.

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RESULTS OF OPERATIONS

Three Months Ended September 30, 2011 Compared to Three Months Ended September 30, 2010

Financial Highlights

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



	Three Months Ended September 30,						Change
	2011			2010
Statement of Income Data:
Revenues:
Services revenues	$	210,681		$	201,390		$	9,291
Product sales	1,613,669			936,989			676,680
Total revenues	1,824,350			1,138,379			685,971

Costs and expenses:
Cost of product sales	1,535,609			860,942			674,667
Operating expenses	135,615			121,748			13,867
General and administrative expenses	17,731			26,860			(9,129		)
Depreciation and amortization expense	42,418			38,539			3,879
Total costs and expenses	1,731,373			1,048,089			683,284

Operating income	92,977			90,290			2,687
Equity in earnings of joint venture	2,599			2,454			145
Interest expense, net	(21,565		)	(20,583		)	(982		)
Other income (expense), net	767			(235		)	1,002
Income before income tax expense	74,778			71,926			2,852
Income tax expense	4,497			3,616			881
Net income	$	70,281		$	68,310		$	1,971

Net income per unit applicable to limited partners	$	0.92		$	0.90		$	0.02

Weighted-average limited partner units outstanding	64,612,423			64,610,549			1,874

Highlights

Net income increased $2.0 million for the three months ended September 30, 2011, compared to the three months ended September 30, 2010, primarily due to a decrease in general and administrative expenses, partially offset by lower segment operating income.

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Segment Operating Highlights

(Thousands of Dollars, Except Barrels/Day Information)



	Three Months Ended September 30,						Change
	2011			2010			Change
Storage:
Throughput (barrels/day)	721,618			673,121			48,497
Throughput revenues	$	21,743		$	19,139		$	2,604
Storage lease revenues	120,146			111,998			8,148
Total revenues	141,889			131,137			10,752
Operating expenses	71,386			66,153			5,233
Depreciation and amortization expense	21,725			19,349			2,376
Segment operating income	$	48,778		$	45,635		$	3,143

Transportation:
Refined products pipelines throughput (barrels/day)	523,279			526,825			(3,546		)
Crude oil pipelines throughput (barrels/day)	319,103			382,845			(63,742		)
Total throughput (barrels/day)	842,382			909,670			(67,288		)
Throughput revenues	$	81,899		$	80,597		$	1,302
Operating expenses	30,796			30,488			308
Depreciation and amortization expense	12,855			12,597			258
Segment operating income	$	38,248		$	37,512		$	736

Asphalt and Fuels Marketing:
Product sales	$	1,618,693		$	937,074		$	681,619
Cost of product sales	1,545,340			864,904			680,436
Gross margin	73,353			72,170			1,183
Operating expenses	41,862			31,575			10,287
Depreciation and amortization expense	6,073			5,138			935
Segment operating income	$	25,418		$	35,457		$	(10,039	)

Consolidation and Intersegment Eliminations:
Revenues	$	(18,131	)	$	(10,429	)	$	(7,702	)
Cost of product sales	(9,731		)	(3,962		)	(5,769		)
Operating expenses	(8,429		)	(6,468		)	(1,961		)
Total	$	29		$	1		$	28

Consolidated Information:
Revenues	$	1,824,350		$	1,138,379		$	685,971
Cost of product sales	1,535,609			860,942			674,667
Operating expenses	135,615			121,748			13,867
Depreciation and amortization expense	40,653			37,084			3,569
Segment operating income	112,473			118,605			(6,132		)
General and administrative expenses	17,731			26,860			(9,129		)
Other depreciation and amortization expense	1,765			1,455			310
Consolidated operating income	$	92,977		$	90,290		$	2,687

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Storage

Throughputs increased 48,497 barrels per day and throughput revenues increased $2.6 million for the three months ended September 30, 2011, compared to the three months ended September 30, 2010, primarily due to operational issues at the refinery served by our Benicia crude oil storage tanks in the third quarter of 2010.

Storage lease revenues increased $8.1 million for the three months ended September 30, 2011, compared to the three months ended September 30, 2010, primarily due to an increase of $5.2 million from completed tank expansion projects at our St. Eustatius and St. James terminals. In addition, revenues increased $2.9 million at our St. Eustatius facility mainly due to higher throughput and related handling fees, as well as new customer contracts and rate escalations.

Operating expenses increased $5.2 million for the three months ended September 30, 2011, compared to the three months ended September 30, 2010, primarily due to maintenance on tanks and increased expenses at our St. Eustatius terminal due to increased marine vessel activity.

Depreciation and amortization expense increased $2.4 million for the three months ended September 30, 2011, compared to the three months ended September 30, 2010, primarily due to the completion of various terminal upgrade and expansion projects.

Transportation

Revenues increased $1.3 million for the three months ended September 30, 2011, compared to the three months ended September 30, 2010, primarily due to:


•	an increase in revenues of $3.1 million and an increase in throughputs of 17,562 barrels per day on refined product pipelines serving the McKee refinery due to operational issues at the refinery during the third quarter of 2010;


•	an increase in revenues of $0.9 million and an increase in throughputs of 22,464 barrels per day from the reactivation of a previously idled pipeline in South Texas;


•	an increase in revenues of $0.9 million, despite decreased throughputs of 4,633 barrels per day, on crude oil pipelines serving the McKee refinery mainly because volumes were shifted to a crude oil pipeline with a higher tariff; and


•	an increase in revenues of $0.7 million on the East Pipeline, despite decreased throughputs of 6,316 barrels per day, due to a tariff increase in July 2011 and increased long-haul deliveries resulting in a higher average tariff.

These increases in revenues were partially offset by:


•	a decrease in revenues of $1.8 million and a decrease in throughputs of 34,568 barrels per day on our Corpus Christi to Three Rivers crude oil pipeline due to a customer receiving crude oil from alternate sources, thus reducing the volume transported on our pipeline;


•	a decrease in revenues of $1.6 million and a decrease in throughputs of 47,574 barrels per day on our crude oil pipelines serving the Ardmore refinery mainly due to operational issues at the refinery and a shift in supply volumes; and


•	a decrease in revenues of $1.3 million on the ammonia pipeline, despite only slightly lower throughputs, due to fewer long-haul movements as flooding in the second quarter continued to cause operational issues in the third quarter of 2011.

Asphalt and Fuels Marketing

Sales and cost of product sales increased $681.6 million and $680.4 million, respectively, resulting in an increase in total gross margin of $1.2 million for the three months ended September 30, 2011, compared to the three months ended September 30, 2010. The change in total gross margin was due to an increase of $19.6 million in the gross margin from our fuels marketing operations, partially offset by a decrease of $18.4 million in the gross margin from our asphalt operations.

The gross margin from our fuels marketing operations increased for the three months ended September 30, 2011, compared to the three months ended September 30, 2010, mainly due to increased volumes and higher sales prices in 2011 for our bunker fuel sales, fuel oil trading and crude trading. The San Antonio Refinery Acquisition in April 2011 also contributed to the increase in gross margin.

The gross margin per barrel for our asphalt operations decreased to $5.96 for the three months ended September 30, 2011, compared to $7.83 for the three months ended September 30, 2010. Weak demand for asphalt in our market combined with asphalt produced by Midwest refiners, which have access to lower cost crude oil, that is being sold in our market contributed to the decrease in gross margin per barrel. The decrease in gross margin was partially offset by a $6.3 million crude oil pricing adjustment associated with our crude supply agreement with PDVSA that serves to keep our actual crude costs in line with a market reference price.

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Operating expenses increased $10.3 million for the three months ended September 30, 2011, compared to the three months ended September 30, 2010, primarily due to higher idle capacity costs at our asphalt refineries, the San Antonio Refinery Acquisition in April 2011 and increased rental expenses associated with our fuels marketing operations.

Depreciation and amortization expense increased $0.9 million for the three months ended September 30, 2011, compared to the three months ended September 30, 2010, primarily due the San Antonio Refinery Acquisition in April 2011 and amortization of deferred costs related to completed turnarounds at our asphalt refineries.

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.

General

General and administrative expenses decreased $9.1 million for the three months ended September 30, 2011, compared to the three months ended September 30, 2010, primarily due to lower compensation expense associated with our long-term incentive plans, which fluctuates with our unit price.

Interest expense, net increased $1.0 million for the three months ended September 30, 2011, compared to the three months ended September 30, 2010, mainly due to the issuance of $450.0 million of 4.80% senior notes in August 2010. This increase in interest expense was partially offset by the amortization of deferred gains related to terminated interest rate swaps, which reduce interest expense over the remaining lives of the associated senior notes.

Other income (expense), net changed by $1.0 million for the three months ended September 30, 2011, compared to the three months ended September 30, 2010. Other income (expense), net included a foreign exchange gain of $3.1 million in 2011, compared to a foreign exchange loss of $0.3 million in 2010, mainly related to one of our Canadian subsidiaries. For the three months ended September 30, 2011, other income (expense), net also includes a contingent loss adjustment of $3.3 million.

Income tax expense increased $0.9 million for the three months ended September 30, 2011, compared to the three months ended September 30, 2010, mainly due to higher taxable income.

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RESULTS OF OPERATIONS

Nine Months Ended September 30, 2011 Compared to Nine Months Ended September 30, 2010

Financial Highlights

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



	Nine Months Ended September 30,						Change
	2011			2010
Statement of Income Data:
Revenues:
Services revenues	$	608,689		$	585,772		$	22,917
Product sales	4,039,461			2,623,077			1,416,384
Total revenues	4,648,150			3,208,849			1,439,301

Costs and expenses:
Cost of product sales	3,797,424			2,422,751			1,374,673
Operating expenses	390,480			363,028			27,452
General and administrative expenses	69,833			76,324			(6,491		)
Depreciation and amortization expense	124,354			114,653			9,701
Total costs and expenses	4,382,091			2,976,756			1,405,335

Operating income	266,059			232,093			33,966
Equity in earnings of joint venture	6,997			7,571			(574		)
Interest expense, net	(62,644		)	(58,059		)	(4,585		)
Other (expense) income, net	(5,699		)	14,882			(20,581		)
Income before income tax expense	204,713			196,487			8,226
Income tax expense	13,311			9,052			4,259
Net income	$	191,402		$	187,435		$	3,967

Net income per unit applicable to limited partners	$	2.49		$	2.55		$	(0.06	)

Weighted-average limited partner units outstanding	64,611,181			62,386,373			2,224,808

Highlights

Net income increased $4.0 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010, primarily due to an increase in segment operating income, partially offset by a decrease in other income. Segment operating income increased $28.0 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010, due to increased operating income from the asphalt and fuels marketing segment and storage segment, partially offset by a decrease in operating income from the transportation segment.

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Segment Operating Highlights

(Thousands of Dollars, Except Barrels/Day Information)



	Nine Months Ended September 30,						Change
	2011			2010			Change
Storage:
Throughput (barrels/day)	679,031			666,635			12,396
Throughput revenues	$	58,388		$	56,085		$	2,303
Storage lease revenues	359,820			330,493			29,327
Total revenues	418,208			386,578			31,630
Operating expenses	213,230			198,186			15,044
Depreciation and amortization expense	64,656			57,004			7,652
Segment operating income	$	140,322		$	131,388		$	8,934

Transportation:
Refined products pipelines throughput (barrels/day)	509,354			529,380			(20,026		)
Crude oil pipelines throughput (barrels/day)	304,554			381,606			(77,052		)
Total throughput (barrels/day)	813,908			910,986			(97,078		)
Throughput revenues	$	226,471		$	232,817		$	(6,346	)
Operating expenses	85,381			88,784			(3,403		)
Depreciation and amortization expense	38,282			38,029			253
Segment operating income	$	102,808		$	106,004		$	(3,196	)

Asphalt and Fuels Marketing:
Product sales	$	4,049,079		$	2,625,994		$	1,423,085
Cost of product sales	3,821,379			2,438,703			1,382,676
Gross margin	227,700			187,291			40,409
Operating expenses	113,506			96,924			16,582
Depreciation and amortization expense	16,505			15,254			1,251
Segment operating income	$	97,689		$	75,113		$	22,576

Consolidation and Intersegment Eliminations:
Revenues	$	(45,608	)	$	(36,540	)	$	(9,068	)
Cost of product sales	(23,955		)	(15,952		)	(8,003		)
Operating expenses	(21,637		)	(20,866		)	(771		)
Total	$	(16	)	$	278		$	(294	)

Consolidated Information:
Revenues	$	4,648,150		$	3,208,849		$	1,439,301
Cost of product sales	3,797,424			2,422,751			1,374,673
Operating expenses	390,480			363,028			27,452
Depreciation and amortization expense	119,443			110,287			9,156
Segment operating income	340,803			312,783			28,020
General and administrative expenses	69,833			76,324			(6,491		)
Other depreciation and amortization expense	4,911			4,366			545
Consolidated operating income	$	266,059		$	232,093		$	33,966

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Storage

Storage revenues increased $31.6 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010, primarily due to:


•	an increase of $11.5 million due to completed tank expansion projects at our St. Eustatius and St. James terminals;


•	an increase of $5.9 million related to our acquisition of three terminals in Mobile County, Alabama in May 2010 and the Turkey Acquisition;


•	an increase of $5.7 million at our St. Eustatius facility mainly due to higher throughput and related handling fees, as well as new customer contracts, rate escalations and higher reimbursable revenues; and


•	an increase of $5.2 million at our UK and Amsterdam terminals, primarily due to the effect of foreign exchange rates, new customer contracts and increased customer utilization.

Operating expenses increased $15.0 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010, primarily due to cancelled capital projects, increased expenses at our St. Eustatius, Amsterdam and UK terminals, the Turkey Acquisition in February 2011 and a full nine months of operating expenses from our three terminals in Mobile County, Alabama acquired in May 2010.

Depreciation and amortization expense increased $7.7 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010, primarily due to the completion of various terminal upgrade and expansion projects, the Turkey Acquisition and our acquisition of three terminals in Mobile County, Alabama in May 2010.

Transportation

Throughputs decreased 97,078 barrels per day and revenues decreased $6.3 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010, primarily due to:


•	a decrease of 61,087 barrels per day and a decrease of $5.9 million on our pipelines serving the Ardmore refinery, mainly due to a turnaround in March and April 2011, followed by operational issues and a shift in supply volumes;


•	a decrease of 25,562 barrels per day and a decrease of $5.6 million on the Houston pipeline mainly due to market conditions that favored exporting instead of shipping on our pipeline;


•	a decrease of 17,721 barrels per day and a decrease of $3.7 million on our Corpus Christi to Three Rivers crude oil pipeline due to a customer receiving crude oil from alternate sources, thus reducing the volume transported on our pipeline; and


•	a decrease of 8,710 barrels per day and a decrease of $1.9 million on our refined product pipelines serving the Three Rivers refinery mainly due to operational issues and the start of a turnaround at the refinery in 2011.

These decreases were partially offset by:


•	an increase of 16,909 barrels per day and an increase in revenues of $7.3 million on pipelines serving the McKee refinery mainly due to increased production in 2011 and operational issues and turnaround activity at the refinery in 2010; and


•	an increase of 5,806 barrels per day and an increase in revenues of $4.1 million on the North Pipeline mainly due to turnaround activity during the second quarter of 2010 at the refinery served by the pipeline.

Operating expenses decreased $3.4 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010, primarily due to a reduction in overhead expenses and lower power expenses consistent with the decrease in throughputs.

Asphalt and Fuels Marketing

Sales and cost of product sales increased $1,423.1 million and $1,382.7 million, respectively, resulting in an increase in total gross margin of $40.4 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010. The increase in total gross margin was primarily due to an increase in the gross margin from our fuels marketing operations resulting from increased volumes and higher sales prices in 2011 for our fuel oil trading and crude trading. The San Antonio Refinery Acquisition in April 2011 also contributed to the increase in gross margin.

Operating expenses increased $16.6 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010, primarily due to higher idle capacity costs at our asphalt refineries, the San Antonio Refinery Acquisition in April 2011 and increased rental expenses associated with our fuels marketing operations.

Depreciation and amortization expense increased $1.3 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010, primarily due to the San Antonio Refinery Acquisition in April 2011 and amortization of deferred costs related to completed turnarounds at our asphalt refineries.

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Consolidation and Intersegment Eliminations

General

General and administrative expenses decreased $6.5 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010, primarily due to lower compensation expense associated with our long-term incentive plans, which fluctuates with our unit price.

Interest expense, net increased $4.6 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010, mainly due to the issuance of $450.0 million of 4.80% senior notes in August 2010. This increase in interest expense was partially offset by the effect of additional fixed-to-floating interest rate swap agreements we entered into in September and October 2010 and the amortization of deferred gains related to terminated interest rate swaps, which reduce interest expense over the remaining lives of the associated senior notes.

Other (expense) income, net changed by $20.6 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010. Other expense, net for the nine months ended September 30, 2011 included $5.0 million of expense associated with the early termination of a third-party storage agreement at our Paulsboro, New Jersey asphalt refinery and a contingent loss adjustment of $3.3 million. Other income, net for the nine months ended September 30, 2010 included a $13.5 million gain from insurance recoveries, which resulted from insurance claims related to damage in the third quarter of 2008 primarily at our Texas City, Texas terminal caused by Hurricane Ike. In addition, other expense, net included a foreign exchange gain of $2.5 million in 2011, compared to a foreign exchange loss of $0.6 million in 2010, related to one of our Canadian subsidiaries.

Income tax expense increased $4.3 million for the nine months ended September 30, 2011, compared to the nine months ended September 30, 2010, mainly due to the reversal of a deferred tax asset valuation allowance included in 2010 income tax expense, which was partially offset by lower taxable income in 2011.

TRENDS AND OUTLOOK

For the full year 2011, we expect our operating income to be higher than 2010 due to increased earnings from our storage segment. However, net income for the full year likely will decline mainly due to a decline in other income. Other income in 2010 included a gain related to insurance proceeds. Lower net income combined with the dilutive effect of our equity issuance in 2010 should cause earnings per unit to decline.

Storage Segment

We are continuing our pursuit of growth in this segment through expansion and optimization of our existing assets. We expect to continue to benefit from internal growth projects in this segment that were completed in the second half of 2010 and in 2011, including our 3.2 million barrel storage tank expansion project at our St. James, Louisiana terminal facility, which was completed during the third quarter of 2011, and projects at our St. Eustatius terminal in the Caribbean. As a result, we expect the storage segment results for the fourth quarter and for the full year 2011 to exceed 2010.

Transportation Segment

We expect throughputs in our transportation segment for the fourth quarter and the full year 2011 to be less than the comparable periods in 2010. Fourth quarter throughputs are expected to be negatively affected by planned turnaround activity at several refineries served by our pipelines. The tariffs on our pipelines regulated by the Federal Energy Regulatory Commission were increased by 6.9 percent effective July 1, 2011. In addition, we completed pipeline projects at the end of the second and third quarter that serve Eagle Ford Shale production, including the reactivation and reversal of a previously idle eight-inch refined products pipeline that now gives us capability to transport Eagle Ford crude and condensate to Valero Energy's Corpus Christi refinery, which should contribute positively to our earnings for the remainder of 2011. However, the tariff increase and the pipeline projects will only partially offset the impact from the lower throughputs. Therefore, we expect the fourth quarter and full year 2011 earnings for this segment to be lower than 2010.

We are continuing our strategy for growth in this segment through construction of new assets and optimization of existing assets, including a plan to construct a new 12-inch pipeline that will connect existing pipeline segments and move crude oil from Corpus Christi to Valero's Three Rivers refinery, as well as a plan to reverse our 16-inch Corpus Christi crude oil pipeline. This new pipeline and the reversal are expected to be completed in the third quarter of 2012. We expect that completion of these and our other announced growth projects will have a favorable impact on our results of operations in future periods.

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Asphalt and Fuels Marketing Segment

During the third quarter 2011, the results for our asphalt and fuels marketing segment, compared to the same period in the prior year, were negatively affected by lower earnings from our asphalt operations. As a result, overall earnings for the segment declined despite improved earnings in our fuels marketing operations and the addition of the San Antonio refinery.

Weak demand for asphalt in our markets contributed to the reduced earnings from our asphalt operations. Additionally, asphalt produced by Midwest refiners, which currently have access to lower-cost crude oil, is being sold in our markets. The combination of weak demand and the pressure of lower-cost asphalt from Midwest refiners have adversely affected our asphalt margins. We expect these factors to continue to exert downward pressure on the margin for our asphalt operations in the fourth quarter. As a result, our asphalt operations could generate a loss for the fourth quarter that could more than offset expected improvements from our fuels marketing operations and the San Antonio refinery, which may result in a loss for the entire segment for the fourth quarter. Nevertheless, we expect the full year 2011 results for the segment to be comparable to 2010 as the expected improvement in our fuels marketing operations and the addition of the San Antonio refinery should offset reduced full-year earnings from our asphalt operations.

The factors negatively affecting the results of our asphalt operations could continue into 2012. In that case, our results from our asphalt operations could continue to deteriorate. However, in 2012 we expect to take steps to address these factors, including obtaining and processing alternative, lower-cost crude for our asphalt refineries. We currently expect the results in 2012 for the asphalt and fuels marketing segment to improve compared to 2011.

Our outlook for the company overall could change depending on, among other things, the prices of crude oil, the state of the economy, changes to refinery maintenance schedules, and other factors that affect overall demand for the products we store, transport and sell, as well as changes in commodity prices for the products we market.

LIQUIDITY AND CAPITAL RESOURCES

General

Our primary cash requirements are for distributions to partners, working capital requirements, including inventory purchases, debt service, capital expenditures, acquisitions and operating expenses. On an annual basis, we attempt 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 operations to meet those requirements, we utilize available borrowing capacity under our revolving credit agreement and, to the extent necessary, funds raised through equity or debt offerings under our shelf registration statements. Additionally, we typically fund our strategic capital expenditures from external sources, primarily borrowings under our revolving credit agreement or funds raised through equity or debt offerings. However, our ability to raise funds by issuing debt or equity depends on many factors beyond our control. The volatility of the capital and credit markets could restrict our ability to issue debt or equity or may increase our cost of capital beyond rates acceptable to us.

Cash Flows for the Nine Months Ended September 30, 2011 and 2010

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



	Nine Months Ended September 30,
	2011			2010
	(Thousands of Dollars)
Net cash provided by (used in):
Operating activities	$	101,871		$	180,833
Investing activities	(352,655		)	(222,392		)
Financing activities	131,878			65,777
Effect of foreign exchange rate changes on cash	(3,001		)	(358		)
Net decrease in cash and cash equivalents	$	(121,907	)	$	23,860

Net cash provided by operating activities for the nine months ended September 30, 2011 was $101.9 million, compared to $180.8 million for the nine months ended September 30, 2010, primarily due to higher investments in working capital in 2011 compared to the same period in 2010. Our working capital increased by $216.4 million in 2011, compared to $99.8 million in 2010. Please refer to the Working Capital Requirements section below for a discussion on the changes in working capital.

For the nine months ended September 30, 2011, net cash provided by operating activities, proceeds from long-term debt

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borrowings, net of repayments, combined with cash on hand, were used to fund our distributions to unitholders and our general partner, capital expenditures primarily related to various terminal projects and two acquisitions.

For the nine months ended September 30, 2010, cash from operating activities, proceeds from long-term and short-term debt borrowings, net of repayments, our issuance of common units and cash on hand were used to fund our distributions to unitholders and our general partner, capital expenditures and an acquisition. Cash flows from investing activities also included insurance proceeds of $13.5 million related to damages caused by Hurricane Ike in the third quarter of 2008 primarily at our Texas City terminal.

2007 Revolving Credit Agreement

As of September 30, 2011, we had $376.2 million available for borrowing under our $1.2 billion five-year revolving credit agreement (the 2007 Revolving Credit Agreement). Due to a covenant in our 2007 Revolving Credit Agreement that requires us to maintain, as of the end of any four consecutive fiscal quarters, a consolidated debt coverage ratio not to exceed 5.00-to-1.00, we may not be able to borrow the maximum available amount. On March 7, 2011, we amended the 2007 Revolving Credit Agreement to exclude unused proceeds from the Gulf Opportunity Zone bond issuances from total indebtedness in the calculation of the consolidated debt coverage ratio. As of September 30, 2011, the consolidated debt coverage ratio was 4.5x. The 2007 Revolving Credit Agreement matures in December 2012, and we do not have any other significant debt maturing until 2012.

Shelf Registration Statements

On April 29, 2011, the Securities and Exchange Commission declared effective our shelf registration statement on Form S-3, which permits us to offer and sell various types of securities, including NuStar Energy common units and debt securities of NuStar Logistics and NuPOP, having an aggregate value of up to $200.0 million (the 2011 Shelf Registration Statement). The 2011 Shelf Registration Statement is in addition to our shelf registration statement on Form S-3 the Securities and Exchange Commission declared effective in May 2010.

On May 23, 2011, in connection with the 2011 Shelf Registration Statement, we entered into an Equity Distribution Agreement (the Equity Distribution Agreement) with Citigroup Global Markets Inc. (Citigroup). Under the Equity Distribution Agreement, we may from time to time sell an aggregate of up to $200.0 million NuStar Energy common units representing limited partner interests, using Citigroup as our sales agent. Sales of common units will be made by means of ordinary brokers' transactions on the New York Stock Exchange at market prices, in block transactions or as otherwise agreed by us and Citigroup. Under the terms of the Equity Distribution Agreement, we may also sell common units to Citigroup as principal for its own account at a price to be agreed upon at the time of sale.

In September 2011, we sold 59,971 NuStar Energy common units under the Equity Distribution Agreement for approximately $3.3 million. We also received $0.1 million from our general partner in order to maintain its 2% general partner interest.

If the capital markets become more volatile, our access to the capital markets may be limited, or we could face increased costs. In addition, it is possible that our ability to access the capital markets may be limited at a time when we would like or need access, which could have an impact on our ability to refinance maturing debt and/or react to changing economic and business conditions.

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 capital expenditures, such as those to expand and upgrade pipeline capacity or 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, as well as certain capital expenditures related to support functions.

During the nine months ended September 30, 2011, our reliability capital expenditures totaled $41.3 million, consisting of $32.8 million primarily related to maintenance upgrade projects at our terminals, which is classified as "Reliability capital expenditures" in the consolidated statements of cash flows, and $8.5 million of turnaround expenditures at our refineries, which is classified as "Investment in other long-term assets" in our consolidated statements of cash flows. Strategic capital expenditures for the nine months ended September 30, 2011 totaled $211.2 million and were primarily related to projects at our St. James, Louisiana and St. Eustatius terminals and our corporate office.

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For the full year 2011, we expect to incur approximately $370.0 million of capital expenditures, including $60.0 million for reliability capital projects and $310.0 million for strategic capital projects, not including acquisitions. Thus far in 2011, we have spent approximately $100.0 million, including working capital, related to the Turkey Acquisition and the San Antonio Refinery Acquisition. We continue to evaluate our capital budget and make changes as economic conditions warrant. Depending upon current economic conditions, our actual capital expenditures for 2011 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 2011, and our internal growth projects can be accelerated or scaled back depending on the condition of the capital markets.

Working Capital Requirements

Our asphalt and fuels marketing segment requires us to make substantial investments in working capital. Increases in the prices of the commodities we purchase cause our working capital requirements to increase, which reduces our liquidity. Our working capital requirements vary with the seasonal nature of asphalt demand as we build and store asphalt inventories during periods of lower demand in order to sell it during periods of higher demand. This seasonal variance in demand also affects our accounts receivable and accounts payable balances, which vary depending on timing of payments.

Within working capital, our inventory balances increased by $176.9 million during the nine months ended September 30, 2011, compared to $114.9 million during the nine months ended September 30, 2010, due to rising crude oil prices in 2011. In addition, accounts receivable increased by $148.8 million during the nine months ended September 30, 2011, compared to $86.0 million during the nine months ended September 30, 2010, mainly due to the timing of payments and higher overall sales, resulting mainly from increased crude trading activity and the San Antonio Refinery Acquisition. Other current assets increased $25.8 million during the nine months ended September 30, 2011, compared to a decrease of $27.3 million during the nine months ended September 30, 2010, primarily due to variations in our derivative positions and an increase in prepaid assets in 2011.

Higher inventory balances also result in higher amounts of accounts payable, offsetting the impact to working capital. In 2011, accounts payable increased $153.6 million, compared to $75.3 million in 2010, due to higher inventory costs and the timing of payments.

Distributions

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



	Three Months Ended September 30,				Nine Months Ended September 30,
	2011		2010		2011		2010
	(Thousands of Dollars, Except Per Unit Data)
General partner interest	$	1,628	$	1,592	$	4,847	$	4,635
General partner incentive distribution	8,972		8,568		26,503		24,736
Total general partner distribution	10,600		10,160		31,350		29,371
Limited partners’ distribution	70,814		69,456		211,019		202,391
Total cash distributions	$	81,414	$	79,616	$	242,369	$	231,762

Cash distributions per unit applicable to limited partners	$	1.095	$	1.075	$	3.265	$	3.205

Distributions declared for the quarter are paid within 45 days following the end of each quarter based on the partnership interests outstanding as of a record date that is set after the end of each quarter.

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Debt Obligations

We are a party to the following debt agreements:


•	the 2007 Revolving Credit Agreement due December 10, 2012, with a balance of $456.3 million as of September 30, 2011;


•	NuStar Logistics’ 6.875% senior notes due July 15, 2012 with a face value of $100.0 million; 6.05% senior notes due March 15, 2013 with a face value of $229.9 million; 7.65% senior notes due April 15, 2018 with a face value of $350.0 million; and 4.80% senior notes due September 1, 2020 with a face value of $450.0 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;


•	$55.4 million revenue bonds due June 1, 2038; $100.0 million revenue bonds due July 1, 2040; $50.0 million revenue bonds due October 1, 2040; $85.0 million revenue bonds due December 1, 2040; and $75.0 million revenue bonds due August 1, 2041 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 $1.8 million as of September 30, 2011, associated with the construction of a crude oil storage facility in Corpus Christi, Texas.

Management believes that, as of September 30, 2011, we are in compliance with all ratios and covenants of both the 2007 Revolving Credit Agreement and the UK Term Loan, which has substantially the same covenants as the 2007 Revolving Credit Agreement. Our other long-term debt obligations do not contain any financial covenants that are different than those contained in the 2007 Revolving Credit Agreement. 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 4 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for a more detailed discussion on certain of our long-term debt agreements.

Interest Rate Swaps

As of September 30, 2011 and December 31, 2010, we were a party to fixed-to-floating interest rate swap agreements and forward-starting swap agreements for the purpose of hedging interest rate risk. The weighted-average interest rate that we paid under our fixed-to-floating interest rate swaps was 2.6% as of September 30, 2011.

The following table aggregates information on our interest rate swap agreements:



	Notional Amount				Fair Value
	September 30, 2011		December 31, 2010		September 30, 2011			December 31, 2010
	(Thousands of Dollars)
Type of interest rate swap agreements:
Fixed-to-floating	$	450,000	$	617,500	$	23,125		$	(18,820	)
Forward-starting	$	500,000	$	500,000	$	(40,930	)	$	35,000

During the nine months ended September 30, 2011, we terminated interest rate swap agreements with an aggregate notional amount of $207.5 million associated with our 6.875%, 6.05% and 7.65% senior notes. We received $12.6 million in connection with the terminations, which is being amortized into "Interest expense, net" over the remaining lives of the related senior notes. Please refer to Note 7 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for a more detailed discussion of our interest rate swaps.

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 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.

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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 5 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements.”

RELATED PARTY TRANSACTIONS

Please refer to Note 8 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for a detailed discussion of our related party transactions.

CRITICAL ACCOUNTING POLICIES

The preparation of financial statements in accordance with United States generally accepted accounting principles 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. Our critical accounting policies are disclosed in our Annual Report on Form 10-K for the year ended December 31, 2010.

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Item 3.	Quantitative and Qualitative Disclosures About Market Risk

Interest Rate Risk

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 fixed-to-floating 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. We also enter into forward-starting interest rate swap agreements to lock in the rate on the interest payments related to forecasted debt issuances. Borrowings under the 2007 Revolving Credit Agreement and Gulf Opportunity Zone Revenue Bonds expose us to increases in applicable interest rates.

The following tables provide 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 our fixed-to-floating 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.



	September 30, 2011
	Expected Maturity Dates
	2011			2012			2013			2014			2015			There- after			Total			Fair Value
	(Thousands of Dollars, Except Interest Rates)
Long-term Debt:
Fixed rate	$	832		$	383,713		$	479,994		$	—		$	—		$	800,000		$	1,664,539		$	1,787,353
Weighted average interest rate	8.0		%	7.4		%	6.0		%	—			—			6.0		%	6.3		%
Variable rate	$	—		$	456,259		$	—		$	—		$	—		$	365,440		$	821,699		$	808,180
Weighted average interest rate	—			0.9		%	—			—			—			0.2		%	0.6		%
Interest Rate Swaps Fixed–to-Floating:
Notional amount	$	—		$	—		$	—		$	—		$	—		$	450,000		$	450,000		$	23,125
Weighted average pay rate	2.5		%	2.6		%	2.8		%	3.4		%	4.0		%	4.9		%	4.0		%
Weighted average receive rate	4.8		%	4.8		%	4.8		%	4.8		%	4.8		%	4.8		%	4.8		%



	December 31, 2010
	Expected Maturity Dates
	2011			2012			2013			2014			2015			There- after			Total			Fair Value
	(Thousands of Dollars, Except Interest Rates)
Long-term Debt:
Fixed rate	$	832		$	383,687		$	479,986		$	—		$	—		$	800,000		$	1,664,505		$	1,775,842
Weighted average interest rate	8.0		%	7.4		%	6.0		%	—			—			6.0		%	6.3		%
Variable rate	$	—		$	188,282		$	—		$	—		$	—		$	290,440		$	478,722		$	473,348
Weighted average interest rate	—			1.0		%	—			—			—			0.3		%	0.6		%
Interest Rate Swaps Fixed–to-Floating:
Notional amount	$	—		$	60,000		$	107,500		$	—		$	—		$	450,000		$	617,500		$	(18,820	)
Weighted average pay rate	2.5		%	3.3		%	4.3		%	5.3		%	6.1		%	6.8		%	5.4		%
Weighted average receive rate	5.2		%	5.2		%	5.0		%	4.8		%	4.8		%	4.8		%	4.9		%

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The following table presents information regarding our forward-starting interest rate swap agreements:



Notional Amount		Period of Hedge	Weighted- Average Fixed Rate		Fair Value
					September 30, 2011			December 31, 2010
(Thousands of Dollars)					(Thousands of Dollars)
$	125,000	03/13 - 03/23	3.5	%	$	(10,588	)	$	8,717
150,000		06/13 - 06/23	3.5	%	(11,718		)	11,243
225,000		02/12 - 02/22	3.1	%	(18,624		)	15,040
$	500,000		3.3	%	$	(40,930	)	$	35,000

Commodity Price Risk

Since the operations of our asphalt and fuels marketing segment exposes us to commodity price risk, we enter into derivative instruments to mitigate the effect of commodity price fluctuations. The derivative instruments we use consist primarily of commodity futures and swap contracts. We have a risk management committee that oversees our trading controls and procedures and certain aspects of risk management. Our risk management committee also reviews all new risk management strategies in accordance with our risk management policy, which was approved by our board of directors.

During the second quarter of 2011, we entered into commodity swap contracts to hedge the price risk associated with the San Antonio Refinery. These contracts fix the purchase price of crude oil and sales prices of refined products for a portion of the expected production of the San Antonio Refinery, thereby mitigating the risk of volatility of future cash flows associated with hedged volumes. These contracts qualified and we designated them as cash flow hedges.

We record commodity derivative instruments in the consolidated balance sheets as assets or liabilities at fair value. We recognize mark-to-market adjustments for derivative instruments designated and qualifying as fair value hedges (Fair Value Hedges) and the related change in the fair value of the associated hedged physical inventory or firm commitment within “Cost of product sales.” For derivative instruments designated and qualifying as cash flow hedges (Cash Flow Hedges), we record the effective 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. For derivative instruments that do not qualify for hedge accounting (Economic Hedges and Other Derivatives), we record the mark-to-market adjustments in “Cost of product sales.”

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The commodity contracts disclosed below represent only those contracts exposed to commodity price risk at the end of the period. Please refer to Note 7 of Condensed Notes to Consolidated Financial Statement in Item 1. “Financial Statements” for the volume and related fair value of all commodity contracts.



	September 30, 2011
	Contract Volumes	Weighted Average				Fair Value of Current Asset (Liability)
	Contract Volumes	Pay Price		Receive Price		Fair Value of Current Asset (Liability)
	(Thousands of Barrels)					(Thousands of Dollars)
Fair Value Hedges:
Futures – long:
(refined products)	15	$	117.19	N/A		$	7
Futures – short:
(refined products)	50	N/A		$	118.78	$	103
Swaps – long:
(refined products)	196	$	95.13	N/A		$	581
Swaps – short:
(refined products)	1,067	N/A		$	96.17	$	3,986

Cash Flow Hedges:
Swaps – long:
(crude oil)	9,988	106.80		N/A		$	(238,832	)
Swaps – short:
(refined products)	9,988	N/A		127.55		$	186,724

Economic Hedges and Other Derivatives:
Futures – long:
(crude oil and refined products)	337	$	79.74	N/A		$	(2,157	)
Futures – short:
(crude oil and refined products)	422	N/A		$	85.91	$	2,428
Swaps – long:
(refined products)	434	$	90.98	N/A		$	(2,432	)
Swaps – short:
(refined products)	673	N/A		$	86.65	$	3,319
Forward purchase contracts:
(crude oil)	4,016	$	100.72	N/A		$	(23,479	)
Forward sales contracts:
(crude oil)	4,016	N/A		$	102.23	$	29,544

Total fair value of open positions exposed to commodity price risk						$	(40,208	)

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	December 31, 2010
	Contract Volumes	Weighted Average				Fair Value of Current Asset (Liability)
	Contract Volumes	Pay Price		Receive Price		Fair Value of Current Asset (Liability)
	(Thousands of Barrels)					(Thousands of Dollars)
Fair Value Hedges:
Futures – short:
(crude oil and refined products)	436	N/A		$	96.00	$	(1,015	)
Swaps – long:
(refined products)	380	$	76.05	N/A		$	(557	)
Swaps – short:
(refined products)	823	N/A		$	74.53	$	(2,541	)

Economic Hedges and Other Derivatives:
Futures – long:
(crude oil and refined products)	278	$	93.80	N/A		$	802
Futures – short:
(crude oil and refined products)	936	N/A		$	100.74	$	(2,102	)
Swaps – long:
(refined products)	385	$	76.27	N/A		$	1,684
Swaps – short:
(refined products)	157	N/A		$	73.22	$	(698	)
Forward purchase contracts:
(crude oil)	4,680	$	85.81	N/A		$	38,434
Forward sales contracts:
(crude oil)	4,680	N/A		$	86.48	$	(38,989	)

Total fair value of open positions exposed to commodity price risk						$	(4,982	)

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Item 4.	Controls and Procedures


(a)	Evaluation of 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) as of the end of the period covered by this report, and has concluded that our disclosure controls and procedures were effective as of September 30, 2011.


(b)	Changes in internal control 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.

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PART II - OTHER INFORMATION

Item 1. Legal Proceedings

The information below describes new proceedings or material developments in proceedings that we previously reported in our annual report on Form 10-K for the year ended December 31, 2010.

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Item 6.	Exhibits



Exhibit Number		Description

*12.1		Statement of Computation of Ratio of Earnings to Fixed Charges

*31.01		Rule 13a-14(a) Certification (under Section 302 of the Sarbanes-Oxley Act of 2002) of principal executive officer

*31.02		Rule 13a-14(a) Certification (under Section 302 of the Sarbanes-Oxley Act of 2002) of principal financial officer

*32.01		Section 1350 Certification (under Section 906 of the Sarbanes-Oxley Act of 2002) of principal executive officer

*32.02		Section 1350 Certification (under Section 906 of the Sarbanes-Oxley Act of 2002) of principal financial officer

**101		The following interactive data files pursuant to Rule 405 of Regulation S-T from NuStar Energy L.P.’s Form 10-Q for the quarter ended September 30, 2011, formatted in XBRL (Extensible Business Reporting Language): (i) Consolidated Balance Sheets, (ii) Consolidated Statements of Income, (iii) Consolidated Statements of Cash Flows, and (iv) Condensed Notes to Consolidated Financial Statements.

*	Filed herewith.
**	Filed electronically herewith.

	In accordance with Rule 406T of regulation S-T, the XBRL information in Exhibit 101 to this quarterly report on Form 10-Q shall not be deemed to be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (Exchange Act), or otherwise subject to the liability of that section, and shall not be incorporated by reference into any registration statement or other document filed under the Securities Act of 1933, as amended, or the Exchange Act. The financial information contained in the XBRL-related documents is “unaudited” or “unreviewed.”

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, 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
		November 7, 2011

By:		/s/ Steven A. Blank
		Steven A. Blank
		Senior Vice President, Chief Financial Officer and Treasurer
		November 7, 2011

By:		/s/ Thomas R. Shoaf
		Thomas R. Shoaf
		Vice President and Controller
		November 7, 2011