NuStar Energy L.P. - FORM 10-Q

Attached files

file	filename
EX-32.02 - EXHIBIT 32.02 - NuStar Energy L.P.	ns3q1710-qex3202.htm
EX-32.01 - EXHIBIT 32.01 - NuStar Energy L.P.	ns3q1710-qex3201.htm
EX-31.02 - EXHIBIT 31.02 - NuStar Energy L.P.	ns3q1710-qex3102.htm
EX-31.01 - EXHIBIT 31.01 - NuStar Energy L.P.	ns3q1710-qex3101.htm
EX-12.01 - EXHIBIT 12.01 - NuStar Energy L.P.	ns3q1710-qex1201.htm
EX-10.02 - EXHIBIT 10.02 - NuStar Energy L.P.	ns3q1710-qex1002.htm

Table of Contents

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, 2017



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.)

19003 IH-10 West San Antonio, Texas		78257
(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 Rule 12b-2 of the Exchange Act:



Large accelerated filer	x	Accelerated filer	o

Non-accelerated filer	o (Do not check if a smaller reporting company)	Smaller reporting company	o

		Emerging growth company	o

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

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, 2017 was 93,032,836.

Table of Contents

NUSTAR ENERGY L.P.

FORM 10-Q

TABLE OF CONTENTS



PART I – FINANCIAL INFORMATION

Item 1.	Financial Statements:

	Consolidated Balance Sheets as of September 30, 2017 and December 31, 2016	3

	Condensed Consolidated Statements of Comprehensive Income for the Three and Nine Months Ended September 30, 2017 and 2016	4

	Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2017 and 2016	5

	Condensed Notes to Consolidated Financial Statements	6

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	29

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	46

Item 4.	Controls and Procedures	49

PART II – OTHER INFORMATION

Item 6.	Exhibits	50

SIGNATURES		51

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, 2017			December 31, 2016
	(Unaudited)
Assets
Current assets:
Cash and cash equivalents	$	33,615		$	35,942
Accounts receivable, net of allowance for doubtful accounts of $7,807 and $7,756 as of September 30, 2017 and December 31, 2016, respectively	152,074			170,293
Receivable from related party	81			317
Inventories	23,297			37,945
Other current assets	24,805			132,686
Total current assets	233,872			377,183
Property, plant and equipment, at cost	6,073,194			5,435,278
Accumulated depreciation and amortization	(1,885,045		)	(1,712,995		)
Property, plant and equipment, net	4,188,149			3,722,283
Intangible assets, net	797,339			127,083
Goodwill	1,095,943			696,637
Deferred income tax asset	1,070			2,051
Other long-term assets, net	102,395			105,308
Total assets	$	6,418,768		$	5,030,545
Liabilities and Partners’ Equity
Current liabilities:
Accounts payable	$	97,854		$	118,686
Short-term debt	68,000			54,000
Current portion of long-term debt	350,007			—
Accrued interest payable	41,811			34,030
Accrued liabilities	60,466			60,485
Taxes other than income tax	19,940			15,685
Income tax payable	2,989			6,510
Total current liabilities	641,067			289,396
Long-term debt	3,232,599			3,014,364
Deferred income tax liability	23,166			22,204
Other long-term liabilities	102,074			92,964
Commitments and contingencies (Note 5)
Partners’ equity:
Series A preferred limited partners (9,060,000 preferred units outstanding as of September 30, 2017 and December 31, 2016)	218,307			218,400
Series B preferred limited partners (15,400,000 preferred units outstanding as of September 30, 2017)	371,613			—
Common limited partners (93,032,099 and 78,616,228 common units outstanding as of September 30, 2017 and December 31, 2016, respectively)	1,873,382			1,455,642
General partner	39,953			31,752
Accumulated other comprehensive loss	(83,393		)	(94,177		)
Total partners’ equity	2,419,862			1,611,617
Total liabilities and partners’ equity	$	6,418,768		$	5,030,545

See Condensed Notes to Consolidated Financial Statements.

Table of Contents

NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

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



	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
Revenues:
Service revenues	$	295,102		$	277,758		$	845,264		$	814,727
Product sales	145,464			163,660			518,220			470,198
Total revenues	440,566			441,418			1,363,484			1,284,925
Costs and expenses:
Cost of product sales	138,078			155,129			490,363			441,736
Operating expenses:
Third parties	116,590			117,432			334,016			313,634
Related party	—			—			—			21,681
Total operating expenses	116,590			117,432			334,016			335,315
General and administrative expenses:
Third parties	25,003			26,957			83,202			62,906
Related party	—			—			—			10,493
Total general and administrative expenses	25,003			26,957			83,202			73,399
Depreciation and amortization expense	69,178			53,946			193,643			160,739
Total costs and expenses	348,849			353,464			1,101,224			1,011,189
Operating income	91,717			87,954			262,260			273,736
Interest expense, net	(45,256		)	(35,022		)	(127,282		)	(103,374		)
Other (expense) income, net	(5,126		)	362			(4,898		)	(10		)
Income before income tax expense	41,335			53,294			130,080			170,352
Income tax expense	2,743			2,153			7,298			9,293
Net income	$	38,592		$	51,141		$	122,782		$	161,059

Basic and diluted net income per common unit (Note 11)	$	0.15		$	0.49		$	0.65		$	1.58
Basic weighted-average common units outstanding	93,031,320			78,031,053			87,392,597			77,934,802
Diluted weighted-average common units outstanding	93,031,320			78,062,889			87,392,597			77,981,299

Comprehensive income	$	44,482		$	48,652		$	133,566		$	120,453

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,
	2017			2016
Cash Flows from Operating Activities:
Net income	$	122,782		$	161,059
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization expense	193,643			160,739
Unit-based compensation expense	7,437			4,820
Amortization of debt related items	4,677			5,762
Loss (gain) from sale or disposition of assets	4,920			(14		)
Deferred income tax (benefit) expense	(106		)	2,989
Changes in current assets and current liabilities (Note 12)	(17,671		)	(12,477		)
Other, net	(4,667		)	(8,329		)
Net cash provided by operating activities	311,015			314,549
Cash Flows from Investing Activities:
Capital expenditures	(220,617		)	(145,414		)
Change in accounts payable related to capital expenditures	13,272			(15,504		)
Proceeds from sale or disposition of assets	2,023			—
Proceeds from Axeon term loan	110,000			—
Acquisitions	(1,461,719		)	—
Net cash used in investing activities	(1,557,041		)	(160,918		)
Cash Flows from Financing Activities:
Proceeds from long-term debt borrowings	1,223,204			523,982
Proceeds from short-term debt borrowings	748,000			462,000
Proceeds from note offering, net of issuance costs	543,313			—
Long-term debt repayments	(1,204,739		)	(410,750		)
Short-term debt repayments	(734,000		)	(539,000		)
Proceeds from issuance of preferred units, net of issuance costs	371,802			—
Proceeds from issuance of common units, net of issuance costs	643,858			27,710
Contributions from general partner	13,597			575
Distributions to preferred unitholders	(26,681		)	—
Distributions to common unitholders and general partner	(331,222		)	(294,153		)
Increase (decrease) in cash book overdrafts	1,564			(12,181		)
Other, net	(6,634		)	(1,418		)
Net cash provided by (used in) financing activities	1,242,062			(243,235		)
Effect of foreign exchange rate changes on cash	1,637			3,404
Net decrease in cash and cash equivalents	(2,327		)	(86,200		)
Cash and cash equivalents as of the beginning of the period	35,942			118,862
Cash and cash equivalents as of the end of the period	$	33,615		$	32,662

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 and Operations

NuStar Energy L.P. (NYSE: NS) is a publicly held Delaware limited partnership engaged in the transportation of petroleum products and anhydrous ammonia, and the terminalling, storage and marketing of petroleum products. Unless otherwise indicated, the terms “NuStar Energy,” “NS,” “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 or NSH) (NYSE: NSH) owns our general partner, Riverwalk Logistics, L.P., and owns an approximate 11% common limited partner interest in us as of September 30, 2017.

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: pipeline, storage and fuels marketing.

Recent Developments

Hurricane Activity. In the third quarter of 2017, parts of the Caribbean and Gulf of Mexico experienced three major hurricanes. Several of our facilities were affected by the hurricanes, with the main impact at our St. Eustatius terminal, which was temporarily shut down. We recorded a $5.0 million loss in “Other (expense) income, net” in the condensed consolidated statements of comprehensive income in the third quarter of 2017 for property damage at our St. Eustatius terminal, which represents the amount of our deductible under our insurance policy. Additionally, we incurred approximately $0.7 million of operating expenses to repair minor property damage at several of our domestic terminals. The shutdown of the St. Eustatius terminal also caused lower revenues for our bunker fuel operations in our fuels marketing segment and lower throughput and associated handling fees in our storage segment. We are still evaluating the extent of property damage at our St. Eustatius terminal, as well as the interruption to our operations; therefore, we are unable to estimate the total impact from the hurricanes at this time. However, we expect that losses incurred above our deductible amount will be covered by our insurance policies.

Navigator Acquisition and Financing Transactions. On May 4, 2017, we completed the acquisition of Navigator Energy Services, LLC for approximately $1.5 billion (the Navigator Acquisition). In order to fund the purchase price, we issued 14,375,000 common units for net proceeds of $657.5 million, issued $550.0 million of 5.625% senior notes for net proceeds of $543.3 million and issued 15,400,000 of our 7.625% Series B Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units (Series B Preferred Units) for net proceeds of $371.8 million. Please refer to Notes 3, 4 and 10 for further discussion.

Axeon Term Loan. On February 22, 2017, we settled and terminated the $190.0 million term loan to Axeon Specialty Products, LLC (the Axeon Term Loan), pursuant to which we also provided credit support, such as guarantees, letters of credit and cash collateral, as applicable, of up to $125.0 million to Axeon Specialty Products, LLC (Axeon). We received $110.0 million in settlement of the Axeon Term Loan, and our obligation to provide ongoing credit support to Axeon ceased. Please refer to Note 6 for further discussion of the Axeon Term Loan and credit support.

Basis of Presentation

These unaudited condensed consolidated financial statements include the accounts of the Partnership and subsidiaries in which the Partnership has a controlling interest. Inter-partnership balances and transactions have been eliminated in consolidation.

These unaudited condensed consolidated financial statements have been prepared in accordance with U.S. 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, 2017 and 2016 included in these Condensed Notes to Consolidated Financial Statements is derived from our unaudited condensed consolidated financial statements. Operating results for the three and nine months ended September 30, 2017 are not necessarily indicative of the results that may be expected for the year ending December 31, 2017. The consolidated balance sheet as of December 31, 2016 has been derived from the audited consolidated financial statements as of that date. These unaudited condensed 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, 2016.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

2. NEW ACCOUNTING PRONOUNCEMENTS

Derivatives and Hedging

In August 2017, the Financial Accounting Standards Board (FASB) issued amended guidance intended to improve the financial reporting of hedging relationships to better portray the economic results of an entity’s risk management activities in its financial statements. The amended guidance also makes certain targeted improvements to simplify the application of current hedge accounting guidance. The guidance is effective for annual and interim periods beginning after December 15, 2018, with early adoption permitted. Certain of the new requirements should be applied prospectively while others should be applied using a modified retrospective transition method. We currently expect to adopt the amended guidance on January 1, 2019 and are assessing the impact of this amended guidance on our financial position, results of operations and disclosures. We plan to provide additional information about the expected financial impact at a future date.

Unit-Based Payments

In May 2017, the FASB issued amended guidance that clarifies when a change to the terms and conditions of a unit-based payment award is accounted for as a modification. Under the amended guidance, an entity will apply modification accounting if the value, vesting or classification of the unit-based payment award changes. The guidance is effective for annual and interim periods beginning after December 15, 2017, and amendments should be applied prospectively. We will adopt these provisions January 1, 2018, and we do not expect the guidance to have a material impact on our financial position, results of operations or disclosures.

Defined Benefit Plans

In March 2017, the FASB issued amended guidance that changes the presentation of net periodic pension cost related to defined benefit plans. Under the amended guidance, the service cost component of net periodic benefit cost will be presented in the same income statement line items as other current employee compensation costs, but the remaining components of net periodic benefit cost will be presented outside of operating income. The changes are effective for annual and interim periods beginning after December 15, 2017, and amendments should be applied retrospectively. We will adopt these provisions January 1, 2018, and we do not expect the guidance to have a material impact on our financial position, results of operations or disclosures.

Goodwill

In January 2017, the FASB issued amended guidance that simplifies the accounting for goodwill impairment by eliminating step 2 of the goodwill impairment test. Under the amended guidance, goodwill impairment will be measured as the excess of the reporting unit’s carrying value over its fair value, not to exceed the carrying amount of goodwill for that reporting unit. The changes are effective for annual and interim periods beginning after December 15, 2019, and amendments should be applied prospectively. Early adoption is permitted for any impairment tests performed after January 1, 2017, and we are currently evaluating whether we will adopt these provisions early. Regardless of our decision, we do not expect the guidance to have a material impact on our financial position, results of operations or disclosures.

Definition of a Business

In January 2017, the FASB issued amended guidance that clarifies the definition of a business used in evaluating whether a set of transferred assets and activities constitutes a business. Under the amended guidance, if substantially all of the fair value of the gross assets acquired is concentrated in a single identifiable asset or a group of similar identifiable assets, the set of transferred assets and activities would not represent a business. To be considered a business, the set of assets transferred is also required to include at least one substantive process that together significantly contribute to the ability to create outputs. In addition, the amended guidance narrows the definition of outputs to be consistent with how outputs are described in the new revenue recognition standard. The changes are effective for annual and interim periods beginning after December 15, 2017, and amendments should be applied prospectively. We will adopt these provisions January 1, 2018, and we do not expect the guidance to have a material impact on our financial position, results of operations or disclosures.

Statement of Cash Flows

In August 2016, the FASB issued amended guidance that clarifies how entities should present certain cash receipts and cash payments on the statement of cash flows, including, but not limited to, debt prepayment or debt extinguishment costs, contingent consideration payments made after a business combination, proceeds from the settlement of insurance claims and distributions received from equity method investees. The changes are effective for annual and interim periods beginning after December 15, 2017, and amendments should be applied retrospectively. We will adopt these provisions January 1, 2018, and we do not expect the guidance to have a material impact on our statements of cash flows or disclosures.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Credit Losses

In June 2016, the FASB issued amended guidance that requires the use of a “current expected loss” model for financial assets measured at amortized cost and certain off-balance sheet credit exposures. Under this model, entities will be required to estimate the lifetime expected credit losses on such instruments based on historical experience, current conditions, and reasonable and supportable forecasts. This amended guidance also expands the disclosure requirements to enable users of financial statements to understand an entity’s assumptions, models and methods for estimating expected credit losses. The changes are effective for annual and interim periods beginning after December 15, 2019, and amendments should be applied using a modified retrospective approach. We currently expect to adopt the amended guidance on January 1, 2020 and are assessing the impact of this amended guidance on our financial position, results of operations and disclosures. We plan to provide additional information about the expected financial impact at a future date.

Leases

In February 2016, the FASB issued amended guidance that requires lessees to recognize the assets and liabilities that arise from most leases on the balance sheet. For lessors, this amended guidance modifies the classification criteria and the accounting for sales-type and direct financing leases. The changes are effective for annual and interim periods beginning after December 15,

2018, and amendments should be applied using a modified retrospective approach for leases that exist or are entered into after the beginning of the earliest comparative period in the financial statements, with the option to use certain expedients. We currently expect to adopt these provisions on January 1, 2019. We have initiated a project to assess the impact of this amended guidance on our financial position, results of operations, disclosures and internal controls and plan to provide additional information about the expected financial impact at a future date.

Financial Instruments

In January 2016, the FASB issued new guidance that addresses certain aspects of recognition, measurement, presentation and disclosure of financial instruments. The changes are effective for annual and interim periods beginning after December 15, 2017, and amendments should be applied by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. We will adopt these provisions January 1, 2018, and we do not expect the guidance to have a material impact on our financial position, results of operations or disclosures.

Revenue Recognition

In May 2014, the FASB and the International Accounting Standards Board jointly issued a comprehensive new revenue recognition standard. In August 2015, the FASB deferred the effective date by one year. The standard is now effective for public entities for annual and interim periods beginning after December 15, 2017, using one of two retrospective transition methods. Early adoption is permitted, but not before the original effective date. The FASB has subsequently issued several updates that amend and/or clarify the new revenue recognition standard. We expect to complete implementation of the new revenue recognition standard by the end of 2017. We currently expect to adopt the new guidance using the modified retrospective approach, under which the cumulative effect of initially applying the new guidance is recognized as an adjustment to the opening balance of retained earnings, in the first quarter of 2018. Based on our analysis completed to date, we do not believe the standard will significantly impact the amount or timing of revenues recognized under the vast majority of our revenue contracts; however, we are continuing to evaluate the impact of this new guidance on our financial position and results of operations. We also intend to provide additional disclosures as required by the new standard, which we are currently assessing.

3. ACQUISITIONS

Navigator Acquisition

On April 11, 2017, we entered into a Membership Interest Purchase and Sale Agreement (the Acquisition Agreement) with FR Navigator Holdings LLC to acquire all of the issued and outstanding limited liability company interests in Navigator Energy Services, LLC (Navigator) for approximately $1.5 billion. We closed on the Navigator Acquisition on May 4, 2017 and funded the purchase price with the net proceeds of the equity and debt issuances described in Notes 4 and 10. We acquired crude oil transportation, pipeline gathering and storage assets located in the Midland Basin of West Texas consisting of: (i) more than 500 miles of crude oil gathering and transportation pipelines with approximately 92,000 barrels per day ship-or-pay volume commitments and deliverability of approximately 412,000 barrels per day; (ii) a pipeline gathering system with more than 200 connected producer tank batteries capable of more than 400,000 barrels per day of pumping capacity covering over 500,000 dedicated acres with fixed fee contracts; and (iii) approximately 1.0 million barrels of crude oil storage capacity with 440,000 barrels contracted to third parties. We collectively refer to the acquired assets as our Permian Crude System. The assets acquired are included in our pipeline segment.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

The Navigator Acquisition broadens our geographic footprint by marking our entry into the Permian Basin and complements our existing asset base. We believe the Permian Crude System will provide a strong growth platform that, when coupled with our assets in the Eagle Ford region, serve to solidify our presence in two of the most prolific basins in the United States.

We accounted for the Navigator Acquisition using the acquisition method. The fair value estimates of the assets acquired and liabilities assumed are based on preliminary assumptions, pending the completion of an independent appraisal and other evaluations as information becomes available to us. The following table reflects the preliminary purchase price allocation as of September 30, 2017:



	Preliminary Purchase Price Allocation
	(Thousands of Dollars)
Accounts receivable	$	4,747
Other current assets	2,436
Property, plant and equipment, net	376,690
Intangible assets (a)	700,000
Goodwill (b)	399,306
Other long-term assets, net	2,125
Current liabilities	(23,585		)
Preliminary purchase price allocation, net of cash acquired	$	1,461,719


(a)	Intangible assets, which consist of customer contracts and relationships, are expected to be amortized over a weighted average period of 20 years.


(b)	The goodwill acquired represents the expected benefit from entering new geographic areas and the anticipated opportunities to generate future cash flows from the assets acquired and potential future projects.

In the third quarter of 2017, goodwill increased by approximately $70.0 million due to valuation adjustments to property, plant and equipment and intangible assets. These adjustments had an immaterial effect on our results of operations. The values used in the purchase price allocation above and estimated useful lives are preliminary and subject to change after we finalize our review of the specific types, nature and condition of Navigator’s property, plant and equipment and intangible assets, and pending the completion of an independent appraisal. A change in the value used for property, plant and equipment or intangible assets may be significant and would cause a corresponding increase or decrease in goodwill.

The condensed consolidated statements of comprehensive income include the results of operations for Navigator commencing on May 4, 2017. The table below presents certain financial information included on the condensed consolidated statements of comprehensive income related to the Navigator Acquisition:



	Three Months Ended September 30, 2017		Nine Months Ended September 30, 2017
	(Thousands of Dollars)
Permian Crude System:
Revenues	$	15,663	$	25,142
Operating income (loss)	$	1,050	$	(2,374	)

Transaction costs:
General and administrative expenses	$	169	$	10,359
Interest expense, net	—		3,688
Total transaction costs	$	169	$	14,047

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

The unaudited pro forma information for the three and nine months ended September 30, 2017 and 2016 presented below combines the historical financial information for Navigator and the Partnership for those periods. The information assumes we completed the Navigator Acquisition on January 1, 2016 and the following:


•	we issued approximately 14.4 million common units;


•	we received a contribution from our general partner of $13.6 million to maintain its 2% interest;


•	we issued 15.4 million Series B Preferred Units;


•	we issued $550.0 million of 5.625% senior notes;


•	additional depreciation and amortization that would have been incurred assuming the fair value adjustments to property, plant and equipment and intangible assets reflected in the preliminary purchase price allocation above; and


•	we satisfied Navigator’s outstanding obligations under its revolving credit agreement.



	Three Months Ended September 30,				Nine Months Ended September 30,
	2017 (a)		2016		2017		2016
	(Thousands of Dollars, Except Per Unit Data)
Revenues	$	440,566	$	449,250	$	1,377,883	$	1,301,419
Net income	$	38,592	$	34,417	$	102,251	$	104,535

Basic and diluted net income per common unit	$	0.15	$	0.16	$	0.31	$	0.50

(a) Represents actual results of operations.

The pro forma information for the nine months ended September 30, 2017 includes transaction costs of approximately $14.0 million, which were directly attributable to the Navigator Acquisition. The pro forma information is unaudited and is not necessarily indicative of the results of operations that would have resulted had the Navigator Acquisition occurred on January 1, 2016 or that may result in the future.

4. DEBT

Revolving Credit Agreement

On August 22, 2017, NuStar Logistics amended its revolving credit agreement (the Revolving Credit Agreement) to extend the maturity date from October 29, 2019 to October 29, 2020, and to increase the borrowing capacity from $1.50 billion to $1.75 billion. The Revolving Credit Agreement was also amended to increase the maximum allowed consolidated debt coverage ratio (as defined in the Revolving Credit Agreement) from 5.00-to-1.00 to 5.50-to-1.00 through the rolling period ending March 31, 2018. Subsequently, the maximum allowed consolidated debt coverage ratio may not exceed 5.00-to-1.00 for any rolling period ending on or after June 30, 2018. If we complete one or more acquisitions for aggregate net consideration of at least $50.0 million, our maximum consolidated debt coverage ratio will increase to 5.50-to-1.00 for two rolling periods.

The requirement not to exceed a maximum consolidated debt coverage ratio may limit the amount we can borrow under the Revolving Credit Agreement to an amount less than the total amount available for borrowing. As of September 30, 2017, letters of credit issued under the Revolving Credit Agreement totaled $7.7 million, and we had $863.8 million available for borrowing. We believe that we are in compliance with the covenants in the Revolving Credit Agreement as of September 30, 2017.

During the nine months ended September 30, 2017, the balance under the Revolving Credit Agreement increased by $39.4 million. The Revolving Credit Agreement bears interest, at our option, based on an alternative base rate, a LIBOR-based rate or a EURIBOR-based rate. The interest rate on the Revolving Credit Agreement is subject to adjustment if our debt rating is downgraded (or upgraded) by certain credit rating agencies. As of September 30, 2017, our weighted-average interest rate related to borrowings under the Revolving Credit Agreement was 2.9%, and we had $878.4 million outstanding.

Issuance of 5.625% Senior Notes

On April 28, 2017, NuStar Logistics issued $550.0 million of 5.625% senior notes due April 28, 2027. We used the net proceeds of $543.3 million from the offering to fund a portion of the purchase price for the Navigator Acquisition and to pay related fees and expenses. The interest on the 5.625% senior notes is payable semi-annually in arrears on April 28 and October 28 of each year beginning on October 28, 2017. The 5.625% senior notes do not have sinking fund requirements. These notes rank equally with existing senior unsecured indebtedness and senior to existing subordinated indebtedness of NuStar Logistics. The 5.625% senior notes contain restrictions on NuStar Logistics’ ability to incur secured indebtedness unless the same security is also provided for the benefit of holders of the senior notes. In addition, the senior notes limit NuStar Logistics’ ability to

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incur indebtedness secured by certain liens, engage in certain sale-leaseback transactions and engage in certain consolidations, mergers or asset sales. The 5.625% senior notes are fully and unconditionally guaranteed by NuStar Energy and NuPOP.

At the option of NuStar Logistics, the 5.625% senior notes may be redeemed in whole or in part at any time at a redemption price, plus accrued and unpaid interest to the redemption date. If we undergo a change of control, followed by a ratings decline within 60 days of a change of control, each holder of the notes may require us to repurchase all or a portion of its notes at a price equal to 101% of the principal amount of the notes, plus any accrued and unpaid interest to the date of repurchase.

Gulf Opportunity Zone Revenue Bonds

In 2008, 2010 and 2011, the Parish of St. James, Louisiana issued, pursuant to the Gulf Opportunity Zone Act of 2005, an aggregate $365.4 million of tax-exempt revenue bonds (the GoZone Bonds) associated with our St. James, Louisiana terminal expansions. The GoZone Bonds bear interest based on a weekly tax-exempt bond market interest rate, and interest is paid monthly. The weighted-average interest rate was 1.0% as of September 30, 2017. Following the issuances, the proceeds were deposited with a trustee and are disbursed to us upon our request for reimbursement of expenditures related to our St. James terminal expansions. We include the amount remaining in trust in “Other long-term assets, net,” and we include the amount of bonds issued in “Long-term debt” on the consolidated balance sheets. For the nine months ended September 30, 2017, we did not receive any proceeds from the trustee, and as of September 30, 2017, the amount remaining in trust totaled $42.5 million.

Receivables Financing Agreement

NuStar Energy and NuStar Finance LLC (NuStar Finance), a special purpose entity and wholly owned subsidiary of NuStar Energy, are parties to a $125.0 million receivables financing agreement with third-party lenders (the Receivables Financing Agreement) and agreements with certain of NuStar Energy’s wholly owned subsidiaries (collectively with the Receivables Financing Agreement, the Securitization Program). NuStar Finance’s sole business consists of purchasing receivables from NuStar Energy’s wholly owned subsidiaries that participate in the Securitization Program and providing these receivables as collateral for NuStar Finance’s revolving borrowings under the Securitization Program. NuStar Finance is a separate legal entity and the assets of NuStar Finance, including these accounts receivable, are not available to satisfy the claims of creditors of NuStar Energy, its subsidiaries selling receivables under the Securitization Program or their affiliates. The amount available for borrowing is based on the availability of eligible receivables and other customary factors and conditions.

On September 20, 2017, the Securitization Program was amended to add certain of NuStar Energy’s wholly owned subsidiaries resulting from the Navigator Acquisition and to extend the Securitization Program’s scheduled termination date from June 15, 2018 to September 20, 2020, with the option to renew for additional 364-day periods thereafter. Borrowings by NuStar Finance under the Receivables Financing Agreement bear interest at the applicable bank rate, as defined under the Receivables Financing Agreement. As of September 30, 2017, $98.6 million of our accounts receivable are included in the Securitization Program. The amount of borrowings outstanding under the Receivables Financing Agreement totaled $46.1 million as of September 30, 2017, which is included in “Long-term debt” on the consolidated balance sheet.

5. COMMITMENTS AND CONTINGENCIES

We have contingent liabilities resulting from various litigation, claims and commitments. 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. We had an accrual of $1.6 million for contingent losses as of September 30, 2017 and none as of December 31, 2016. The amount that will ultimately be paid may differ from the recorded accruals, and the timing of such payments is uncertain. In addition, 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.

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 for identical assets or liabilities in active markets; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable, such as quoted prices for similar assets or liabilities in active markets or quoted prices for identical assets or liabilities in markets that are not active; and Level 3, defined as unobservable inputs for 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.

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Recurring Fair Value Measurements

The following assets and liabilities are measured at fair value on a recurring basis:



	September 30, 2017
	Level 1			Level 2			Level 3		Total
	(Thousands of Dollars)
Assets:
Other current assets:
Product imbalances	$	6,960		$	—		$	—	$	6,960
Liabilities:
Accrued liabilities:
Product imbalances	$	(2,164	)	$	—		$	—	$	(2,164	)
Commodity derivatives	(791		)	—			—		(791		)
Interest rate swaps	—			(7,280		)	—		(7,280		)
Other long-term liabilities:
Interest rate swaps	—			(4,043		)	—		(4,043		)
Total	$	(2,955	)	$	(11,323	)	$	—	$	(14,278	)



	December 31, 2016
	Level 1			Level 2			Level 3			Total
	(Thousands of Dollars)
Assets:
Other current assets:
Product imbalances	$	1,551		$	—		$	—		$	1,551
Commodity derivatives	—			155			—			155
Other long-term assets, net:
Interest rate swaps	—			1,314			—			1,314
Total	$	1,551		$	1,469		$	—		$	3,020
Liabilities:
Accrued liabilities:
Product imbalances	$	(1,577	)	$	—		$	—		$	(1,577	)
Commodity derivatives	(4,887		)	(165		)	—			(5,052		)
Other long-term liabilities:
Guarantee liability	—			—			(1,230		)	(1,230		)
Interest rate swaps	—			(2,632		)	—			(2,632		)
Total	$	(6,464	)	$	(2,797	)	$	(1,230	)	$	(10,491	)

Product Imbalances. Since we value our assets and liabilities related to product imbalances using quoted market prices in active markets as of the reporting date, we include these product imbalances in Level 1 of the fair value hierarchy.

Commodity Derivatives. We base the fair value of certain of our commodity derivative instruments on quoted prices on an exchange; accordingly, we include these items in Level 1 of the fair value hierarchy. We also had derivative instruments for which we determined fair value using industry pricing services and other observable inputs, such as quoted prices on an exchange for similar derivative instruments, and we included these derivative instruments in Level 2 of the fair value hierarchy. See Note 7 for a discussion of our derivative instruments.

Interest Rate Swaps. Because we estimate the fair value of our forward-starting interest rate swaps using discounted cash flows, which use observable inputs such as time to maturity and market interest rates, we include these interest rate swaps in Level 2 of the fair value hierarchy.

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Guarantees. In 2014, we sold our remaining 50% ownership interest in Axeon and agreed to provide them with credit support, such as guarantees, letters of credit and cash collateral, as applicable, of up to $125.0 million. As of December 31, 2016, we provided guarantees totaling $54.1 million, and one guarantee that did not specify a maximum amount. Our estimate of the fair value was based on significant inputs not observable in the market and thus fell within Level 3 of the fair value hierarchy. In conjunction with the termination of the Axeon Term Loan on February 22, 2017 discussed in the following section, our obligation to provide credit support to Axeon ceased.

Fair Value of Financial Instruments

We recognize cash equivalents, receivables, payables and debt in our consolidated balance sheets at their carrying amounts. The fair values of these financial instruments, except for long-term debt, approximate their carrying amounts.

The estimated fair values and carrying amounts of long-term debt, including the current portion, and the Axeon Term Loan were as follows:



	September 30, 2017		December 31, 2016
	Long-term Debt		Long-term Debt		Axeon Term Loan
	(Thousands of Dollars)
Fair value	$	3,694,877	$	3,084,762	$	110,000
Carrying amount	$	3,582,606	$	3,014,364	$	110,000

Long-term Debt. We estimated the fair value of our publicly traded senior notes based upon quoted prices in active markets; therefore, we determined that the fair value of our publicly traded senior notes falls in Level 1 of the fair value hierarchy. For our other debt, for which a quoted market price is not available, we estimated the fair value using a discounted cash flow analysis using current incremental borrowing rates for similar types of borrowing arrangements and determined that the fair value falls in Level 2 of the fair value hierarchy.

Axeon Term Loan. In December 2016, Lindsay Goldberg LLC, the private investment firm that owned Axeon, informed us that they entered into an agreement to sell Axeon’s retail asphalt sales and distribution business (the Axeon Sale), and we entered into an agreement with Axeon (the Axeon Letter Agreement) to settle and terminate the Axeon Term Loan for $110.0 million upon closing of the Axeon Sale. Therefore, we reduced the carrying amount of the Axeon Term Loan to $110.0 million and reclassified the Axeon Term Loan from “Other long-term assets, net” to “Other current assets” on the consolidated balance sheet as of December 31, 2016. The Axeon Sale closed on February 22, 2017, at which time we received the $110.0 million payment in accordance with the Axeon Letter Agreement. Furthermore, the Axeon Term Loan and our obligation to provide ongoing credit support to Axeon all terminated concurrently on February 22, 2017.

7. DERIVATIVES AND RISK MANAGEMENT ACTIVITIES

We utilize various derivative instruments to manage our exposure to interest rate risk and commodity price risk. Our risk management policies and procedures are designed to monitor interest rates, futures and swap positions and over-the-counter positions, as well as physical commodity volumes, grades, locations and delivery schedules, to help ensure that our hedging activities address our market risks.

Interest Rate Risk

We are a party to certain interest rate swap agreements to manage our exposure to changes in interest rates, which include forward-starting interest rate swap agreements related to forecasted debt issuances in 2018 and 2020. We entered into these 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. Under the terms of the swaps, we pay a fixed rate and receive a rate based on the three-month USD LIBOR. These swaps qualify as cash flow hedges, and we designate them as such. We record the effective portion of mark-to-market adjustments as a component of “Accumulated other comprehensive income (loss)” (AOCI), and the amount in AOCI will be recognized in “Interest expense, net” as the forecasted interest payments occur or if the interest payments are probable not to occur. As of September 30, 2017 and December 31, 2016, the aggregate notional amount of forward-starting interest rate swaps totaled $600.0 million.

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Commodity Price Risk

We are exposed to market risks related to the volatility of petroleum product prices. In order to reduce the risk of commodity price fluctuations with respect to our petroleum 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. 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 we record associated gains and losses in net income. Our risk management committee 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. We ceased marketing crude oil in the second quarter of 2017 and exited our heavy fuels trading operations in the third quarter of 2017, thereby reducing our overall hedging activity.

The volume of commodity contracts is based on open derivative positions and represents the combined volume of our long and short open positions on an absolute basis, which totaled 1.1 million barrels and 4.7 million barrels as of September 30, 2017 and December 31, 2016, respectively. We had $0.3 million and $1.8 million of margin deposits as of September 30, 2017 and December 31, 2016, respectively.

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, 2017		December 31, 2016		September 30, 2017			December 31, 2016
		(Thousands of Dollars)
Derivatives Designated as Hedging Instruments:
Interest rate swaps	Other long-term assets, net	$	—	$	1,314	$	—		$	—
Commodity contracts	Accrued liabilities	18		144		(2		)	(3,566		)
Interest rate swaps	Accrued liabilities	—		—		(7,280		)	—
Interest rate swaps	Other long-term liabilities	—		—		(4,043		)	(2,632		)
Total		18		1,458		(11,325		)	(6,198		)

Derivatives Not Designated as Hedging Instruments:
Commodity contracts	Other current assets	—		265		—			(110		)
Commodity contracts	Accrued liabilities	655		9,128		(1,462		)	(10,758		)
Total		655		9,393		(1,462		)	(10,868		)

Total Derivatives		$	673	$	10,851	$	(12,787	)	$	(17,066	)

Certain of our derivative instruments are eligible for offset in the consolidated balance sheets and subject to master netting arrangements. Under our master netting arrangements, there is a legally enforceable right to offset amounts, and we intend to settle such amounts on a net basis. The following are the net amounts presented on the consolidated balance sheets:



Commodity Contracts	September 30, 2017			December 31, 2016
	(Thousands of Dollars)
Net amounts of assets presented in the consolidated balance sheets	$	—		$	155
Net amounts of liabilities presented in the consolidated balance sheets	$	(791	)	$	(5,052	)

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We recognize the impact of our commodity contracts on earnings in “Cost of product sales” on the condensed consolidated statements of comprehensive income, and that impact was as follows:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
	(Thousands of Dollars)
Derivatives Designated as Fair Value Hedging Instruments:
(Loss) gain recognized in income on derivative	$	(1,134	)	$	558		$	1,327		$	(6,246	)
Gain (loss) recognized in income on hedged item	1,111			329			(1,036		)	10,134
(Loss) gain recognized in income for ineffective portion	$	(23	)	$	887		$	291		$	3,888

Derivatives Not Designated as Hedging Instruments:
Loss recognized in income on derivative	$	(132	)	$	(153	)	$	(218	)	$	(157	)

Our interest rate swaps had the following impact on earnings:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
	(Thousands of Dollars)
Derivatives Designated as Cash Flow Hedging Instruments:
Loss recognized in other comprehensive income on derivative (effective portion)	$	(2,064	)	$	(2,035	)	$	(10,005	)	$	(52,213	)
Loss reclassified from AOCI into interest expense, net (effective portion)	$	(1,584	)	$	(2,011	)	$	(5,112	)	$	(6,391	)

As of September 30, 2017, we expect to reclassify a loss of $5.5 million to “Interest expense, net” within the next twelve months associated with unwound forward-starting interest rate swaps.

8. RELATED PARTY TRANSACTIONS

Employee Transfer from NuStar GP, LLC. On March 1, 2016, NuStar GP, LLC, the general partner of our general partner and a wholly owned subsidiary of NuStar GP Holdings, transferred and assigned to NuStar Services Company LLC (NuStar Services Co), a wholly owned subsidiary of NuStar Energy, all of NuStar GP, LLC’s employees and related benefit plans, programs, contracts and policies (the Employee Transfer). As a result of the Employee Transfer, we pay employee costs directly and sponsor the long-term incentive plan and other employee benefit plans. Please refer to Note 9 for a discussion of our employee benefit plans.

GP Services Agreement. Prior to the Employee Transfer, our operations were managed by NuStar GP, LLC under a services agreement effective January 1, 2008, pursuant to which employees of NuStar GP, LLC performed services for our U.S. operations. Employees of NuStar GP, LLC provided services to us and NuStar GP Holdings; therefore, we reimbursed NuStar GP, LLC for all employee costs incurred prior to the Employee Transfer, other than the expenses allocated to NuStar GP Holdings. For the nine months ended September 30, 2016, we reimbursed NuStar GP, LLC $21.7 million and $10.5 million for operating expenses and general and administrative expenses, respectively.

In conjunction with the Employee Transfer, we entered into an Amended and Restated Services Agreement with NuStar GP, LLC, effective March 1, 2016 (the Amended GP Services Agreement). The Amended GP Services Agreement provides that we will furnish administrative services necessary to conduct the business of NuStar GP Holdings. NuStar GP Holdings will compensate us for these services through an annual fee of $1.0 million, subject to adjustment based on the annual merit increase percentage applicable to our employees for the most recently completed fiscal year and for changes in level of service. The Amended GP Services Agreement will terminate on March 1, 2020 and will automatically renew for successive two-year terms, unless terminated by either party.

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9. EMPLOYEE BENEFIT PLANS

Effective March 1, 2016, in connection with the Employee Transfer, we assumed sponsorship and responsibility for the defined benefit plans and defined contribution plans described below. Prior to the Employee Transfer, NuStar GP, LLC sponsored and maintained these employee benefit plans and we reimbursed all costs incurred by NuStar GP, LLC related to these employee benefit plans at cost.

The NuStar Pension Plan (the Pension Plan) is a qualified non-contributory defined benefit pension plan that provides eligible U.S. employees with retirement income as calculated under a cash balance formula. The NuStar Excess Pension Plan (the Excess Pension Plan) is a nonqualified deferred compensation plan that provides benefits to a select group of management or other highly compensated employees. The Pension Plan and Excess Pension Plan are collectively referred to as the Pension Plans. In September 2017, we contributed $11.0 million to the Pension Plans.

We also sponsor a contributory medical benefits plan for U.S. employees that retired prior to April 1, 2014. For employees that retire on or after April 1, 2014, we provide partial reimbursement for eligible third-party health care premiums.

The following table summarizes the components of net periodic benefit cost (income) for the Pension Plans and other postretirement benefits on a combined basis for periods prior to the Employee Transfer and after the Employee Transfer:



	Pension Plans						Other Postretirement Benefits
	2017			2016			2017			2016
	(Thousands of Dollars)
For the three months ended September 30:
Service cost	$	2,239		$	1,926		$	115		$	105
Interest cost	1,127			1,006			107			100
Expected return on assets	(1,603		)	(1,353		)	—			—
Amortization of prior service credit	(515		)	(516		)	(286		)	(286		)
Amortization of net loss	371			273			47			45
Net periodic benefit cost (income)	$	1,619		$	1,336		$	(17	)	$	(36	)

For the nine months ended September 30:
Service cost	$	6,717		$	5,778		$	341		$	315
Interest cost	3,381			3,018			323			300
Expected return on assets	(4,808		)	(4,056		)	—			—
Amortization of prior service credit	(1,546		)	(1,549		)	(858		)	(858		)
Amortization of net loss	1,113			819			143			135
Net periodic benefit cost (income)	$	4,857		$	4,010		$	(51	)	$	(108	)

10. PARTNERS’ EQUITY

Amendment of Partnership Agreement

In the second quarter of 2017, our general partner amended and restated our partnership agreement in connection with the issuance of the Series B Preferred Units as described below and the Navigator Acquisition to waive up to an aggregate $22.0 million of the quarterly incentive distributions to our general partner for any NS common units issued from the date of the Acquisition Agreement (other than those attributable to NS common units issued under any equity compensation plan) for ten consecutive quarters, starting with the distributions for the second quarter of 2017.

Issuance of Common Units

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Issuance of Series B Preferred Units

On April 28, 2017, we issued 15,400,000 of our Series B Preferred Units representing limited partner interests at a price of $25.00 per unit. We used the net proceeds of $371.8 million from the issuance of the Series B Preferred Units to fund a portion of the purchase price for the Navigator Acquisition and to pay related fees and expenses.

Distributions on the Series B Preferred Units are payable out of any legally available funds, accrue and are cumulative from the date of original issuance of the Series B Preferred Units and are payable on the 15^th day of each of March, June, September and December of each year to holders of record on the first day of each payment month. The initial distribution rate on the Series B Preferred Units to, but not including, June 15, 2022 is 7.625% per annum of the $25.00 liquidation preference per unit (equal to $1.90625 per unit per annum). On and after June 15, 2022, distributions on the Series B Preferred Units accumulate at a percentage of the $25.00 liquidation preference equal to an annual floating rate of the three-month LIBOR plus a spread of 5.643%. The Series B Preferred Units rank equal to our Series A Preferred Units and senior to our common units with respect to distribution rights and rights upon liquidation.

At any time on or after June 15, 2022, we may redeem our Series B Preferred Units, in whole or in part, at a redemption price of $25.00 per unit plus an amount equal to all accumulated and unpaid distributions to, but not including, the date of redemption, whether or not declared. We may also redeem the Series B Preferred Units upon the occurrence of certain rating events or a change of control as defined in our partnership agreement. In the case of the latter instance, if we choose not to redeem the Series B Preferred Units, the preferred unitholders may have the ability to convert the Series B Preferred Units to common units at the then applicable conversion rate. Holders of the Series B Preferred Units have no voting rights except for certain exceptions set forth in our partnership agreement.

Partners’ Equity Activity

The following table summarizes changes to our partners’ equity (in thousands of dollars):



Balance as of January 1, 2017	$	1,611,617
Net income	122,782
Unit-based compensation	4,164
Other comprehensive income	10,784
Distributions to partners	(358,138		)
Issuance of preferred and common units, including contribution from general partner	1,029,257
Other	(604		)
Balance as of September 30, 2017	$	2,419,862

Accumulated Other Comprehensive Income (Loss)

The balance of and changes in the components included in AOCI were as follows:



	Foreign Currency Translation			Cash Flow Hedges			Pension and Other Postretirement Benefits			Total
	(Thousands of Dollars)
Balance as of January 1, 2017	$	(69,069	)	$	(22,258	)	$	(2,850	)	$	(94,177	)
Other comprehensive income (loss):
Other comprehensive income (loss) before reclassification adjustments	16,825			(10,005		)	—			6,820
Net gain on pension costs reclassified into operating expense	—			—			(858		)	(858		)
Net gain on pension costs reclassified into general and administrative expense	—			—			(290		)	(290		)
Net loss on cash flow hedges reclassified into interest expense, net	—			5,112			—			5,112
Other comprehensive income (loss)	16,825			(4,893		)	(1,148		)	10,784
Balance as of September 30, 2017	$	(52,244	)	$	(27,151	)	$	(3,998	)	$	(83,393	)

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Allocations of Net Income

Our partnership agreement sets forth the calculation to be used to determine the amount and priority of cash distributions that the unitholders and general partner will receive. The partnership agreement also contains provisions for the allocation of net income to the unitholders and the general partner. Our net income for each quarterly reporting period is first allocated to the preferred limited partner unitholders in an amount equal to the earned distributions for the respective reporting period and then to the general partner in an amount equal to the general partner’s incentive distribution calculated based upon the declared distribution for the respective reporting period. We allocate the remaining net income or loss among the common unitholders (98%) and general partner (2%), as set forth in our partnership agreement.

The following table details the calculation of net income applicable to the general partner:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
	(Thousands of Dollars, Except Percentage Data)
Net income attributable to NuStar Energy L.P.	$	38,592		$	51,141		$	122,782		$	161,059
Less preferred limited partner interest	12,153			—			26,916			—
Less general partner incentive distribution	10,912			10,890			34,736			32,500
Net income after general partner incentive distribution and preferred limited partner interest	15,527			40,251			61,130			128,559
General partner interest allocation	2		%	2		%	2		%	2		%
General partner interest allocation of net income	311			805			1,223			2,571
General partner incentive distribution	10,912			10,890			34,736			32,500
Net income applicable to general partner	$	11,223		$	11,695		$	35,959		$	35,071

Cash Distributions

General Partner and Common Limited Partners. The following table reflects the allocation of total cash distributions to the general partner and common limited partners applicable to the period in which the distributions were earned:



	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
	(Thousands of Dollars, Except Per Unit Data)
General partner interest	$	2,302	$	1,976	$	6,947	$	5,898
General partner incentive distribution	10,912		10,890		34,736		32,500
Total general partner distribution	13,214		12,866		41,683		38,398
Common limited partners’ distribution	101,870		85,943		305,652		256,513
Total cash distributions	$	115,084	$	98,809	$	347,335	$	294,911

Cash distributions per unit applicable to common limited partners	$	1.095	$	1.095	$	3.285	$	3.285

The following table summarizes information related to our quarterly cash distributions to our general partner and common limited partners:



Quarter Ended	Cash Distributions Per Unit		Total Cash Distributions		Record Date	Payment Date
			(Thousands of Dollars)
September 30, 2017 (a)	$	1.095	$	115,084	November 9, 2017	November 14, 2017
June 30, 2017	$	1.095	$	115,083	August 7, 2017	August 11, 2017
March 31, 2017	$	1.095	$	117,168	May 8, 2017	May 12, 2017
December 31, 2016	$	1.095	$	98,971	February 8, 2017	February 13, 2017


(a)	The distribution was announced on October 18, 2017.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Preferred Units. The following table summarizes information related to our quarterly cash distributions on our Series A and Series B Preferred Units:



Period	Cash Distributions Per Unit		Total Cash Distributions		Record Date	Payment Date
			(Thousands of Dollars)
Series A Preferred Units:
September 15, 2017 - December 14, 2017 (a)	$	0.53125	$	4,813	December 1, 2017	December 15, 2017
June 15, 2017 - September 14, 2017	$	0.53125	$	4,813	September 1, 2017	September 15, 2017
March 15, 2017 - June 14, 2017	$	0.53125	$	4,813	June 1, 2017	June 15, 2017
November 25, 2016 - March 14, 2017	$	0.64930556	$	5,883	March 1, 2017	March 15, 2017

Series B Preferred Units:
September 15, 2017 - December 14, 2017 (a)	$	0.47657	$	7,339	December 1, 2017	December 15, 2017
April 28, 2017 - September 14, 2017	$	0.725434028	$	11,172	September 1, 2017	September 15, 2017


(a)	The distribution was announced on October 18, 2017.

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NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

11. NET INCOME PER COMMON UNIT

Basic and diluted net income per common unit is determined pursuant to the two-class method. Under this method, all earnings are allocated to our common limited partners and participating securities based on their respective rights to receive distributions earned during the period. Participating securities include our general partner interest and restricted units awarded under our long-term incentive plan.

We compute basic net income per common unit by dividing net income attributable to common units by the weighted-average number of common units outstanding during the period. We compute diluted net income per common unit by dividing net income attributable to our common limited partners by the sum of (i) the weighted-average number of common units outstanding during the period and (ii) the effect of dilutive potential common units outstanding during the period. Dilutive potential common units include contingently issuable performance units awarded under our long-term incentive plan.

The following table details the calculation of net income per common unit:



	Three Months Ended September 30,						Nine Months Ended September 30,
	2017			2016			2017			2016
	(Thousands of Dollars, Except Unit and Per Unit Data)
Net income attributable to NuStar Energy L.P.	$	38,592		$	51,141		$	122,782		$	161,059
Less: Distributions to general partner (including incentive distribution rights)	13,214			12,866			41,683			38,398
Less: Distributions to common limited partners	101,870			85,943			305,652			256,513
Less: Distributions to preferred limited partners	12,153			—			26,916			—
Less: Distribution equivalent rights to restricted units	707			650			2,134			1,969
Distributions in excess of earnings	$	(89,352	)	$	(48,318	)	$	(253,603	)	$	(135,821	)

Net income attributable to common units:
Distributions to common limited partners	$	101,870		$	85,943		$	305,652		$	256,513
Allocation of distributions in excess of earnings	(87,565		)	(47,351		)	(248,531		)	(133,103		)
Total	$	14,305		$	38,592		$	57,121		$	123,410

Basic weighted-average common units outstanding	93,031,320			78,031,053			87,392,597			77,934,802

Diluted common units outstanding:
Basic weighted-average common units outstanding	93,031,320			78,031,053			87,392,597			77,934,802
Effect of dilutive potential common units	—			31,836			—			46,497
Diluted weighted-average common units outstanding	93,031,320			78,062,889			87,392,597			77,981,299

Basic and diluted net income per common unit	$	0.15		$	0.49		$	0.65		$	1.58

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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,
	2017			2016
	(Thousands of Dollars)
Decrease (increase) in current assets:
Accounts receivable	$	24,538		$	(15,200	)
Receivable from related party	236			—
Inventories	15,497			3,767
Other current assets	1,176			4,809
Increase (decrease) in current liabilities:
Accounts payable	(52,910		)	7,706
Payable to related party, net	—			806
Accrued interest payable	7,829			(6,672		)
Accrued liabilities	(10,702		)	(7,477		)
Taxes other than income tax	279			3,670
Income tax payable	(3,614		)	(3,886		)
Changes in current assets and current liabilities	$	(17,671	)	$	(12,477	)

The above changes in current assets and current liabilities differ from changes between amounts reflected in the applicable consolidated balance sheets due to:


•	current assets and current liabilities acquired during the period;


•	the change in the amount accrued for capital expenditures;


•	the effect of foreign currency translation; and


•	changes in the fair values of our interest rate swap agreements.

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



	Nine Months Ended September 30,
	2017		2016
	(Thousands of Dollars)
Cash paid for interest, net of amount capitalized	$	112,335	$	112,796
Cash paid for income taxes, net of tax refunds received	$	10,090	$	9,873

13. SEGMENT INFORMATION

Our reportable business segments consist of pipeline, storage 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 the transportation of petroleum products and anhydrous ammonia, the terminalling and storage of petroleum products and the marketing of petroleum products. Intersegment revenues result from storage agreements with wholly owned subsidiaries of NuStar Energy at rates consistent with the rates charged to third parties for storage.

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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,
	2017			2016			2017			2016
	(Thousands of Dollars)
Revenues:
Pipeline	$	137,426		$	122,481		$	385,406		$	362,929
Storage:
Third parties	155,677			152,746			453,995			445,497
Intersegment	2,394			5,021			10,066			16,543
Total storage	158,071			157,767			464,061			462,040
Fuels marketing	147,463			166,191			524,083			476,499
Consolidation and intersegment eliminations	(2,394		)	(5,021		)	(10,066		)	(16,543		)
Total revenues	$	440,566		$	441,418		$	1,363,484		$	1,284,925

Operating income (loss):
Pipeline	$	61,119		$	58,922		$	179,015		$	186,739
Storage	59,323			58,420			169,131			166,496
Fuels marketing	(1,532		)	(337		)	3,897			282
Consolidation and intersegment eliminations	(1		)	(1		)	—			—
Total segment operating income	118,909			117,004			352,043			353,517
General and administrative expenses	25,003			26,957			83,202			73,399
Other depreciation and amortization expense	2,189			2,093			6,581			6,382
Total operating income	$	91,717		$	87,954		$	262,260		$	273,736

Total assets by reportable segment were as follows:



	September 30, 2017		December 31, 2016
	(Thousands of Dollars)
Pipeline	$	3,451,302	$	2,024,633
Storage	2,665,426		2,522,586
Fuels marketing	104,140		168,347
Total segment assets	6,220,868		4,715,566
Other partnership assets	197,900		314,979
Total consolidated assets	$	6,418,768	$	5,030,545

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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 100% indirectly owned subsidiaries, NuStar Logistics and NuPOP. The senior and subordinated notes issued by NuStar Logistics are fully and unconditionally guaranteed by NuStar Energy and NuPOP. 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, 2017

(Thousands of Dollars)



	NuStar Energy		NuStar Logistics		NuPOP		Non-Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Cash and cash equivalents	$	894	$	28	$	—	$	32,693	$	—		$	33,615
Receivables, net	—		114		—		152,041		—			152,155
Inventories	—		1,733		6,580		14,984		—			23,297
Other current assets	118		9,378		5,405		9,904		—			24,805
Intercompany receivable	—		3,183,871		—		—		(3,183,871		)	—
Total current assets	1,012		3,195,124		11,985		209,622		(3,183,871		)	233,872
Property, plant and equipment, net	—		1,904,510		582,390		1,701,249		—			4,188,149
Intangible assets, net	—		60,886		—		736,453		—			797,339
Goodwill	—		149,453		170,652		775,838		—			1,095,943
Investment in wholly owned subsidiaries	2,992,907		24,152		1,291,487		816,809		(5,125,355		)	—
Deferred income tax asset	—		—		—		1,070		—			1,070
Other long-term assets, net	378		65,393		27,782		8,842		—			102,395
Total assets	$	2,994,297	$	5,399,518	$	2,084,296	$	4,249,883	$	(8,309,226	)	$	6,418,768
Liabilities and Partners’ Equity
Accounts payable	$	2,201	$	24,752	$	13,812	$	57,089	$	—		$	97,854
Short-term debt	—		68,000		—		—		—			68,000
Current portion of long-term debt	—		350,007		—		—		—			350,007
Accrued interest payable	—		41,780		—		31		—			41,811
Accrued liabilities	822		19,980		10,527		29,137		—			60,466
Taxes other than income tax	63		7,551		4,922		7,404		—			19,940
Income tax payable	—		704		3		2,282		—			2,989
Intercompany payable	487,956		—		1,228,444		1,467,471		(3,183,871		)	—
Total current liabilities	491,042		512,774		1,257,708		1,563,414		(3,183,871		)	641,067
Long-term debt	—		3,186,908		—		45,691		—			3,232,599
Deferred income tax liability	—		1,862		13		21,291		—			23,166
Other long-term liabilities	—		48,605		9,895		43,574		—			102,074
Total partners’ equity	2,503,255		1,649,369		816,680		2,575,913		(5,125,355		)	2,419,862
Total liabilities and partners’ equity	$	2,994,297	$	5,399,518	$	2,084,296	$	4,249,883	$	(8,309,226	)	$	6,418,768

Table of Contents

NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Condensed Consolidating Balance Sheets

December 31, 2016

(Thousands of Dollars)



	NuStar Energy		NuStar Logistics		NuPOP		Non-Guarantor Subsidiaries		Eliminations			Consolidated
Assets
Cash and cash equivalents	$	870	$	5	$	—	$	35,067	$	—		$	35,942
Receivables, net	—		3,040		—		167,570		—			170,610
Inventories	—		2,216		2,005		33,724		—			37,945
Other current assets	61		120,350		1,829		10,446		—			132,686
Intercompany receivable	—		1,308,415		—		57,785		(1,366,200		)	—
Total current assets	931		1,434,026		3,834		304,592		(1,366,200		)	377,183
Property, plant and equipment, net	—		1,935,172		589,139		1,197,972		—			3,722,283
Intangible assets, net	—		71,033		—		56,050		—			127,083
Goodwill	—		149,453		170,652		376,532		—			696,637
Investment in wholly owned subsidiaries	1,964,736		34,778		1,221,717		874,649		(4,095,880		)	—
Deferred income tax asset	—		—		—		2,051		—			2,051
Other long-term assets, net	1,255		63,586		28,587		11,880		—			105,308
Total assets	$	1,966,922	$	3,688,048	$	2,013,929	$	2,823,726	$	(5,462,080	)	$	5,030,545
Liabilities and Partners’ Equity
Accounts payable	$	2,436	$	24,272	$	7,124	$	84,854	$	—		$	118,686
Short-term debt	—		54,000		—		—		—			54,000
Accrued interest payable	—		34,008		—		22		—			34,030
Accrued liabilities	1,070		7,118		10,766		41,531		—			60,485
Taxes other than income tax	125		6,854		3,253		5,453		—			15,685
Income tax payable	—		1,326		5		5,179		—			6,510
Intercompany payable	257,497		—		1,108,703		—		(1,366,200		)	—
Total current liabilities	261,128		127,578		1,129,851		137,039		(1,366,200		)	289,396
Long-term debt	—		2,956,338		—		58,026		—			3,014,364
Deferred income tax liability	—		1,862		13		20,329		—			22,204
Other long-term liabilities	—		34,358		9,436		49,170		—			92,964
Total partners’ equity	1,705,794		567,912		874,629		2,559,162		(4,095,880		)	1,611,617
Total liabilities and partners’ equity	$	1,966,922	$	3,688,048	$	2,013,929	$	2,823,726	$	(5,462,080	)	$	5,030,545

Table of Contents

NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Condensed Consolidating Statements of Comprehensive Income (Loss)

For the Three Months Ended September 30, 2017

(Thousands of Dollars)



	NuStar Energy			NuStar Logistics			NuPOP			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	127,980		$	58,871		$	253,854		$	(139	)	$	440,566
Costs and expenses	332			77,668			38,709			232,279			(139		)	348,849
Operating (loss) income	(332		)	50,312			20,162			21,575			—			91,717
Equity in earnings (loss) of subsidiaries	38,896			(4,558		)	20,809			39,508			(94,655		)	—
Interest income (expense), net	28			(46,247		)	(1,455		)	2,418			—			(45,256		)
Other income (expense), net	—			57			(8		)	(5,175		)	—			(5,126		)
Income (loss) before income tax expense	38,592			(436		)	39,508			58,326			(94,655		)	41,335
Income tax expense	—			115			1			2,627			—			2,743
Net income (loss)	$	38,592		$	(551	)	$	39,507		$	55,699		$	(94,655	)	$	38,592

Comprehensive income (loss)	$	38,592		$	(1,031	)	$	39,507		$	62,069		$	(94,655	)	$	44,482

Condensed Consolidating Statements of Comprehensive Income

For the Three Months Ended September 30, 2016

(Thousands of Dollars)



	NuStar Energy			NuStar Logistics			NuPOP			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	131,696		$	53,158		$	256,925		$	(361	)	$	441,418
Costs and expenses	252			79,443			37,957			236,173			(361		)	353,464
Operating (loss) income	(252		)	52,253			15,201			20,752			—			87,954
Equity in earnings (loss) of subsidiaries	51,397			(44		)	25,819			43,205			(120,377		)	—
Interest (expense) income, net	—			(43,832		)	2,165			6,645			—			(35,022		)
Other (expense) income, net	(4		)	378			(8		)	(4		)	—			362
Income before income tax expense (benefit)	51,141			8,755			43,177			70,598			(120,377		)	53,294
Income tax expense (benefit)	—			588			(29		)	1,594			—			2,153
Net income	$	51,141		$	8,167		$	43,206		$	69,004		$	(120,377	)	$	51,141

Comprehensive income	$	51,141		$	8,143		$	43,206		$	66,539		$	(120,377	)	$	48,652

Table of Contents

NUSTAR ENERGY L.P. AND SUBSIDIARIES

CONDENSED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

Condensed Consolidating Statements of Comprehensive Income (Loss)

For the Nine Months Ended September 30, 2017

(Thousands of Dollars)



	NuStar Energy			NuStar Logistics			NuPOP			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	380,504		$	161,689		$	822,064		$	(773	)	$	1,363,484
Costs and expenses	1,327			237,086			106,296			757,288			(773		)	1,101,224
Operating (loss) income	(1,327		)	143,418			55,393			64,776			—			262,260
Equity in earnings (loss) of subsidiaries	124,073			(10,625		)	69,770			121,002			(304,220		)	—
Interest income (expense), net	36			(129,551		)	(4,160		)	6,393			—			(127,282		)
Other income (expense), net	—			140			1			(5,039		)	—			(4,898		)
Income before income tax expense	122,782			3,382			121,004			187,132			(304,220		)	130,080
Income tax expense	—			81			3			7,214			—			7,298
Net income	$	122,782		$	3,301		$	121,001		$	179,918		$	(304,220	)	$	122,782

Comprehensive income (loss)	$	122,782		$	(1,592	)	$	121,001		$	195,595		$	(304,220	)	$	133,566

Condensed Consolidating Statements of Comprehensive Income (Loss)

For the Nine Months Ended September 30, 2016

(Thousands of Dollars)



	NuStar Energy			NuStar Logistics			NuPOP			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	383,836		$	159,272		$	742,890		$	(1,073	)	$	1,284,925
Costs and expenses	1,204			221,839			104,958			684,261			(1,073		)	1,011,189
Operating (loss) income	(1,204		)	161,997			54,314			58,629			—			273,736
Equity in earnings (loss) of subsidiaries	162,248			(5,362		)	71,273			131,294			(359,453		)	—
Interest (expense) income, net	—			(124,619		)	5,699			15,546			—			(103,374		)
Other income (expense), net	18			400			(18		)	(410		)	—			(10		)
Income before income tax expense (benefit)	161,062			32,416			131,268			205,059			(359,453		)	170,352
Income tax expense (benefit)	3			1,281			(24		)	8,033			—			9,293
Net income	$	161,059		$	31,135		$	131,292		$	197,026		$	(359,453	)	$	161,059

Comprehensive income (loss)	$	161,059		$	(14,687	)	$	131,292		$	202,242		$	(359,453	)	$	120,453

Table of Contents

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, 2017

(Thousands of Dollars)



	NuStar Energy			NuStar Logistics			NuPOP			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Net cash provided by operating activities	$	355,864		$	128,395		$	72,711		$	290,917		$	(536,872	)	$	311,015
Cash flows from investing activities:
Capital expenditures	—			(34,964		)	(18,138		)	(167,515		)	—			(220,617		)
Change in accounts payable related to capital expenditures	—			(1,223		)	4,445			10,050			—			13,272
Proceeds from sale or disposition of assets	—			1,947			17			59			—			2,023
Investment in subsidiaries	(1,262,000		)	—			—			(126		)	1,262,126			—
Proceeds from Axeon term loan	—			110,000			—			—			—			110,000
Acquisitions	—			—			—			(1,461,719		)	—			(1,461,719		)
Net cash (used in) provided by investing activities	(1,262,000		)	75,760			(13,676		)	(1,619,251		)	1,262,126			(1,557,041		)
Cash flows from financing activities:
Debt borrowings	—			1,901,504			—			69,700			—			1,971,204
Note offering, net of issuance costs	—			543,313			—			—			—			543,313
Debt repayments	—			(1,856,739		)	—			(82,000		)	—			(1,938,739		)
Issuance of preferred units, net of issuance costs	371,802			—			—			—			—			371,802
Issuance of common units, net of issuance costs	643,858			—			—			—			—			643,858
General partner contribution	13,597			—			—			—			—			13,597
Distributions to preferred unitholders	(26,681		)	(13,340		)	(13,341		)	(13,342		)	40,023			(26,681		)
Distributions to common unitholders and general partner	(331,222		)	(165,611		)	(165,611		)	(165,627		)	496,849			(331,222		)
Contributions from affiliates	—			1,262,000			—			126			(1,262,126		)	—
Net intercompany activity	238,172			(1,873,773		)	119,917			1,515,684			—			—
Other, net	(3,366		)	(1,486		)	—			(218		)	—			(5,070		)
Net cash provided by (used in) financing activities	906,160			(204,132		)	(59,035		)	1,324,323			(725,254		)	1,242,062
Effect of foreign exchange rate changes on cash	—			—			—			1,637			—			1,637
Net increase (decrease) in cash and cash equivalents	24			23			—			(2,374		)	—			(2,327		)
Cash and cash equivalents as of the beginning of the period	870			5			—			35,067			—			35,942
Cash and cash equivalents as of the end of the period	$	894		$	28		$	—		$	32,693		$	—		$	33,615

Table of Contents

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, 2016

(Thousands of Dollars)



	NuStar Energy			NuStar Logistics			NuPOP			Non-Guarantor Subsidiaries			Eliminations			Consolidated
Net cash provided by operating activities	$	292,572		$	97,253		$	118,436		$	281,544		$	(475,256	)	$	314,549
Cash flows from investing activities:
Capital expenditures	—			(53,491		)	(43,329		)	(48,594		)	—			(145,414		)
Change in accounts payable related to capital expenditures	—			(15,086		)	2,645			(3,063		)	—			(15,504		)
Investment in subsidiaries	—			—			(212,900		)	—			212,900			—
Net cash used in investing activities	—			(68,577		)	(253,584		)	(51,657		)	212,900			(160,918		)
Cash flows from financing activities:
Debt borrowings	—			965,082			—			20,900			—			985,982
Debt repayments	—			(918,550		)	—			(31,200		)	—			(949,750		)
Issuance of common units, net of issuance costs	27,710			—			—			—			—			27,710
General partner contribution	575			—			—			—			—			575
Distributions to common unitholders and general partner	(294,153		)	(147,076		)	(147,077		)	(147,093		)	441,246			(294,153		)
Contributions from affiliates	—			—			—			178,890			(178,890		)	—
Net intercompany activity	(25,372		)	75,165			282,226			(332,019		)	—			—
Other, net	(1,406		)	(3,298		)	(1		)	(8,894		)	—			(13,599		)
Net cash (used in) provided by financing activities	(292,646		)	(28,677		)	135,148			(319,416		)	262,356			(243,235		)
Effect of foreign exchange rate changes on cash	—			—			—			3,404			—			3,404
Net decrease in cash and cash equivalents	(74		)	(1		)	—			(86,125		)	—			(86,200		)
Cash and cash equivalents as of the beginning of the period	885			4			—			117,973			—			118,862
Cash and cash equivalents as of the end of the period	$	811		$	3		$	—		$	31,848		$	—		$	32,662

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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, 2016, 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 we are 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. (NYSE: NS) is engaged in the transportation of petroleum products and anhydrous ammonia, and the terminalling, storage and marketing of petroleum products. Unless otherwise indicated, the terms “NuStar Energy,” “NS,” “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 or NSH) (NYSE: NSH) owns our general partner, Riverwalk Logistics, L.P., and owns an approximate 11% common limited partner interest in us as of September 30, 2017. Our Management’s Discussion and Analysis of Financial Condition and Results of Operations is presented in seven sections:


•	Overview


•	Results of Operations


•	Trends and Outlook


•	Liquidity and Capital Resources


•	Related Party Transactions


•	Critical Accounting Policies


•	New Accounting Pronouncements

Recent Developments

Navigator Acquisition and Financing Transactions. On May 4, 2017, we completed the acquisition of Navigator Energy Services, LLC for approximately $1.5 billion (the Navigator Acquisition). In order to fund the purchase price, we issued 14,375,000 common units for net proceeds of $657.5 million, issued $550.0 million of 5.625% senior notes for net proceeds of $543.3 million and issued 15,400,000 of our 7.625% Series B Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units (Series B Preferred Units) for net proceeds of $371.8 million. We collectively refer to the acquired assets as our Permian Crude System. The assets acquired are included in our pipeline segment. Please refer to Notes 3, 4 and 10 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for further discussion.

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Axeon Term Loan. On February 22, 2017, we settled and terminated the $190.0 million term loan to Axeon Specialty Products, LLC (the Axeon Term Loan), pursuant to which we also provided credit support, such as guarantees, letters of credit and cash collateral, as applicable, of up to $125.0 million to Axeon Specialty Products, LLC (Axeon). We received $110.0 million in settlement of the Axeon Term Loan, and our obligation to provide ongoing credit support to Axeon ceased. Please refer to Note 6 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for further discussion of the Axeon Term Loan and credit support.

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 consist of three reportable business segments: pipeline, storage and fuels marketing.

Pipeline. We own 3,140 miles of refined product pipelines and 1,830 miles of crude oil pipelines and gathering lines, as well as approximately 5.0 million barrels of storage capacity, which comprise our Central West System. In addition, we own 2,370 miles of refined product pipelines, consisting of the East and North Pipelines, and a 2,000-mile ammonia pipeline (the Ammonia Pipeline), which together comprise our Central East System. The East and North Pipelines have storage capacity of approximately 6.7 million barrels. We charge tariffs on a per barrel basis for transporting refined products, crude oil and other feedstocks in our refined product and crude oil pipelines and on a per ton basis for transporting anhydrous ammonia in the Ammonia Pipeline.

Storage. We own terminals and storage facilities in the United States, Canada, Mexico, the Netherlands, including St. Eustatius in the Caribbean, and the United Kingdom (UK), with approximately 84.7 million barrels of storage capacity. Revenues for the storage segment include fees for tank storage agreements, whereby a customer agrees to pay for a certain amount of storage in a tank over a period of time (storage terminal revenues), and throughput agreements, whereby a customer pays a fee per barrel for volumes moving through our terminals (throughput terminal revenues).

Fuels Marketing. Within our fuels marketing operations, we purchase petroleum products for resale. The results of operations for the fuels marketing segment depend largely on the margin between our costs and the sales prices of the products we market. Therefore, the results of operations for this segment are more sensitive to changes in commodity prices compared to the operations of the pipeline and storage segments. We enter into derivative contracts to attempt to mitigate the effects of commodity price fluctuations.

We ceased marketing crude oil in the second quarter of 2017 and exited our heavy fuels trading operations in the third quarter of 2017. These actions are in line with our goal of reducing our exposure to commodity margins, and instead focusing on our core, fee-based pipeline and storage segments. Going forward, the only operations remaining in our fuels marketing segment will be our bunkering operations at our St. Eustatius and Texas City terminals, as well as our butane blending operations.

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;


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


•	economic factors, such as commodity price volatility that impact our fuels marketing segment and the drilling activity by our crude oil production customers; and


•	factors that impact the operations served by our pipeline and storage assets, such as utilization rates and maintenance turnaround schedules of our refining company customers and drilling activity by our crude oil production customers.

Current Market Conditions

The price of crude oil has recovered only modestly since its sharp initial decline in 2014 and subsequent historic lows during 2015 and 2016. This year, global supply and demand have moved into balance, which seems to have reduced crude price volatility, but crude prices remain stalled at approximately 50% of their 2014 levels. Most energy industry experts now project only modest price recovery through the end of 2018.

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Increases or decreases in the price of crude oil affect sectors across the energy industry, including our customers in crude oil production, refining and trading, in different ways at different points in any given price cycle. For example, U.S. crude oil producers reduced their capital spending relatively early in this sustained low price cycle, which reduced drilling activity and lowered production, particularly in shale play regions with higher relative drilling costs. As this cycle has continued, producers focused their trimmed-back spending on the most capital-efficient regions, such as, notably, the Permian Basin. Refiners, on the other hand, have benefitted from lower crude oil prices, to the extent they have been able to take advantage of the combination of lower feedstock prices, especially those positioned for healthy regional demand for their refined products; however, as refined product inventories increase, refiners are incentivized to reduce their production levels, which in turn may reduce their ability to benefit from low crude prices. Crude oil traders focus less on the current market commodity price than on whether that price is higher or lower than future market prices: if the future price for a product is believed to be higher than the current market price, or a “contango market,” traders are more likely to purchase and store products to sell in the future at the higher price. On the other hand, when the current price of crude oil nears or exceeds the expected future market price, or “backwardation,” as is currently the case, traders are no longer incentivized to purchase and store product for future sale.

RESULTS OF OPERATIONS

Three Months Ended September 30, 2017 Compared to Three Months Ended September 30, 2016

Financial Highlights

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



	Three Months Ended September 30,						Change
	2017			2016			Change
Statement of Income Data:
Revenues:
Service revenues	$	295,102		$	277,758		$	17,344
Product sales	145,464			163,660			(18,196		)
Total revenues	440,566			441,418			(852		)

Costs and expenses:
Cost of product sales	138,078			155,129			(17,051		)
Operating expenses	116,590			117,432			(842		)
General and administrative expenses	25,003			26,957			(1,954		)
Depreciation and amortization expense	69,178			53,946			15,232
Total costs and expenses	348,849			353,464			(4,615		)

Operating income	91,717			87,954			3,763
Interest expense, net	(45,256		)	(35,022		)	(10,234		)
Other (expense) income, net	(5,126		)	362			(5,488		)
Income before income tax expense	41,335			53,294			(11,959		)
Income tax expense	2,743			2,153			590
Net income	$	38,592		$	51,141		$	(12,549	)
Basic and diluted net income per common unit	$	0.15		$	0.49		$	(0.34	)
Basic weighted-average common units outstanding	93,031,320			78,031,053			15,000,267

Overview

Net income decreased $12.5 million for the three months ended September 30, 2017, compared to the three months ended September 30, 2016, primarily due to increased interest expense and other expense, net, which were partially offset by a slight increase in segment operating income.

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Segment Operating Highlights

(Thousands of Dollars, Except Barrels/Day Information)



	Three Months Ended September 30,						Change
	2017			2016			Change
Pipeline:
Refined products pipelines throughput (barrels/day)	527,148			536,509			(9,361		)
Crude oil pipelines throughput (barrels/day)	679,721			384,359			295,362
Total throughput (barrels/day)	1,206,869			920,868			286,001
Throughput revenues	$	137,426		$	122,481		$	14,945
Operating expenses	41,463			41,331			132
Depreciation and amortization expense	34,844			22,228			12,616
Segment operating income	$	61,119		$	58,922		$	2,197
Storage:
Throughput (barrels/day)	294,544			810,470			(515,926		)
Throughput terminal revenues	$	21,120		$	30,239		$	(9,119	)
Storage terminal revenues	136,951			127,528			9,423
Total revenues	158,071			157,767			304
Operating expenses	66,603			69,722			(3,119		)
Depreciation and amortization expense	32,145			29,625			2,520
Segment operating income	$	59,323		$	58,420		$	903
Fuels Marketing:
Product sales and other revenue	$	147,463		$	166,191		$	(18,728	)
Cost of product sales	140,110			157,567			(17,457		)
Gross margin	7,353			8,624			(1,271		)
Operating expenses	8,885			8,961			(76		)
Segment operating loss	$	(1,532	)	$	(337	)	$	(1,195	)
Consolidation and Intersegment Eliminations:
Revenues	$	(2,394	)	$	(5,021	)	$	2,627
Cost of product sales	(2,032		)	(2,438		)	406
Operating expenses	(361		)	(2,582		)	2,221
Total	$	(1	)	$	(1	)	$	—
Consolidated Information:
Revenues	$	440,566		$	441,418		$	(852	)
Cost of product sales	138,078			155,129			(17,051		)
Operating expenses	116,590			117,432			(842		)
Depreciation and amortization expense	66,989			51,853			15,136
Segment operating income	118,909			117,004			1,905
General and administrative expenses	25,003			26,957			(1,954		)
Other depreciation and amortization expense	2,189			2,093			96
Consolidated operating income	$	91,717		$	87,954		$	3,763

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Pipeline

Total revenues increased $14.9 million and throughputs increased 286,001 barrels per day for the three months ended September 30, 2017, compared to the three months ended September 30, 2016, primarily due to:


•	an increase in revenues of $15.7 million and an increase in throughputs of 282,145 barrels per day resulting from our Permian Crude System acquired in the Navigator Acquisition;


•	an increase in revenues of $1.9 million and an increase in throughputs of 4,998 barrels per day due to maintenance downtime in 2016 on a portion of the Ammonia Pipeline, as well as operational issues in 2016 at certain plants served by the pipeline; and


•	an increase in revenues of $1.7 million and an increase in throughputs of 5,162 barrels per day due to increased production at the refinery served by our North Pipeline.

These increases were partially offset by:


•	a decrease in revenues of $2.1 million and a decrease in throughputs of 15,995 barrels per day due to a turnaround and operational issues at the refineries served by the East Pipeline in the third quarter of 2017;


•	a decrease in revenues of $1.9 million and a decrease in throughputs of 3,113 barrels per day due to operational issues at the refinery served by our McKee Systems; and


•	a decrease in revenues of $0.5 million and a decrease in throughputs of 7,126 barrels per day on our Eagle Ford System mainly due to reduced production in this sustained low crude oil price environment.

Operating expenses remained flat for the three months ended September 30, 2017, compared to the three months ended September 30, 2016. Increased operating expenses of $3.6 million resulting from our recently acquired Permian Crude System were offset by a decrease of $2.4 million in maintenance and regulatory expenses and a decrease of $1.2 million from product imbalances on the East Pipeline.

Depreciation and amortization expense increased $12.6 million for the three months ended September 30, 2017, compared to the three months ended September 30, 2016, mainly due to our acquisition of the Permian Crude System.

Storage

Beginning January 1, 2017, our agreements for our refinery crude storage tanks at Corpus Christi, TX, Texas City, TX and Benicia, CA changed from throughput-based to storage-based. Excluding the effect from the change to these agreements, throughput terminal revenues would have increased $1.6 million and throughputs would have decreased 24,525 barrels per day for the three months ended September 30, 2017, compared to the three months ended September 30, 2016. Throughput terminal revenues increased $3.3 million, despite decreased throughputs of 9,780 barrels per day, at our Corpus Christi North Beach terminal, mainly resulting from our acquisition of assets from Martin Operating Partnership L.P. in December 2016 (the Martin Terminal Acquisition). The benefit of the Martin Terminal Acquisition was partially offset by lower revenues and throughputs resulting from a decrease in Eagle Ford Shale crude oil being shipped to Corpus Christi. Also, revenues decreased $1.6 million and throughputs decreased 32,439 barrels per day at our Paulsboro, NJ terminal as a customer diverted barrels to other terminals.

Excluding the effect of the change to the refinery storage tank agreements described above, storage terminal revenues would have decreased $0.4 million for the three months ended September 30, 2017, compared to the three months ended September 30, 2016, primarily due to:


•	a decrease of $4.4 million in domestic revenues, mainly at our St. James, LA terminal due to reduced unit train activity and at our Texas City, TX terminal as a result of the exit from our heavy fuels trading operations and tanks out of service; and


•	a decrease in revenues of $1.3 million at our Point Tupper terminal mainly due to a loss in customer base, tanks out of service and lower reimbursable revenues.

These decreases were mostly offset by an increase in revenues of $4.7 million at our St. Eustatius terminal, mainly due to new customer contracts and rate escalations, partially offset by decreased lower throughput and associated handling fees as a result of the shutdown of the terminal and damage caused by hurricane activity in the third quarter of 2017.

Operating expenses decreased $3.1 million for the three months ended September 30, 2017, compared to the three months ended September 30, 2016, mainly due to:


•	a decrease of $2.0 million in reimbursable expenses mainly at our Texas City, TX and Point Tupper terminals, consistent with the decrease in reimbursable revenues;


•	a decrease of $1.4 million in maintenance and regulatory expenses, spread across various terminals; and


•	a decrease of $1.1 million in internal overhead expenses, mainly due to higher capitalized overhead related to capital storage projects in 2017.

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These decreases were partially offset by an increase in operating expenses of $1.8 million resulting from the Martin Terminal Acquisition.

Depreciation and amortization expense increased $2.5 million for the three months ended September 30, 2017, compared to the three months ended September 30, 2016, as a result of the Martin Terminal Acquisition and the completion of various storage projects.

Fuels Marketing

Segment operating loss increased $1.2 million for the three months ended September 30, 2017, compared to the three months ended September 30, 2016, mainly due to lower gross margins from our bunker fuel operations at our St. Eustatius terminal, as well as the temporary shutdown of the terminal caused by hurricane activity in the third quarter of 2017.

Consolidation and Intersegment Eliminations

Revenue and operating expense eliminations primarily relate to storage fees charged to the fuels marketing segment by the storage segment. Cost of product sales eliminations represent expenses charged to the fuels marketing segment for costs associated with inventory that are expensed once the inventory is sold.

General

General and administrative expenses decreased $2.0 million for the three months ended September 30, 2017, compared to the three months ended September 30, 2016, primarily due to a reduction in employee benefit costs.

Interest expense, net increased $10.2 million for the three months ended September 30, 2017, compared to the three months ended September 30, 2016, mainly due to the issuance of $550.0 million of 5.625% senior notes in April 2017. Interest expense also increased as a result of lower interest income due to the termination of the Axeon Term Loan in February 2017. Please refer to Note 6 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for a discussion of the Axeon Term Loan and related credit support.

For the three months ended September 30, 2017, we recognized other expense, net of $5.1 million mainly due to property damage at our St. Eustatius terminal resulting from hurricane activity in the third quarter of 2017.

Income tax expense increased $0.6 million for the three months ended September 30, 2017, compared to the three months ended September 30, 2016, primarily due to an increase in the margin tax in Texas as a result of the Navigator Acquisition.

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Nine Months Ended September 30, 2017 Compared to Nine Months Ended September 30, 2016

Financial Highlights

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



	Nine Months Ended September 30,						Change
	2017			2016			Change
Statement of Income Data:
Revenues:
Service revenues	$	845,264		$	814,727		$	30,537
Product sales	518,220			470,198			48,022
Total revenues	1,363,484			1,284,925			78,559

Costs and expenses:
Cost of product sales	490,363			441,736			48,627
Operating expenses	334,016			335,315			(1,299		)
General and administrative expenses	83,202			73,399			9,803
Depreciation and amortization expense	193,643			160,739			32,904
Total costs and expenses	1,101,224			1,011,189			90,035

Operating income	262,260			273,736			(11,476		)
Interest expense, net	(127,282		)	(103,374		)	(23,908		)
Other expense, net	(4,898		)	(10		)	(4,888		)
Income before income tax expense	130,080			170,352			(40,272		)
Income tax expense	7,298			9,293			(1,995		)
Net income	$	122,782		$	161,059		$	(38,277	)
Basic and diluted net income per common unit	$	0.65		$	1.58		$	(0.93	)
Basic weighted-average common units outstanding	87,392,597			77,934,802			9,457,795

Overview

Net income decreased $38.3 million for the nine months ended September 30, 2017, compared to the nine months ended September 30, 2016, primarily due to increases in interest expense, general and administrative expenses and other expense, net. Segment operating income remained flat as a decline in the pipeline segment was mostly offset by increases in the fuels marketing and storage segments.

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Segment Operating Highlights

(Thousands of Dollars, Except Barrels/Day Information)



	Nine Months Ended September 30,						Change
	2017			2016			Change
Pipeline:
Refined products pipelines throughput (barrels/day)	524,277			532,275			(7,998		)
Crude oil pipelines throughput (barrels/day)	549,898			398,229			151,669
Total throughput (barrels/day)	1,074,175			930,504			143,671
Throughput revenues	$	385,406		$	362,929		$	22,477
Operating expenses	114,734			110,494			4,240
Depreciation and amortization expense	91,657			65,696			25,961
Segment operating income	$	179,015		$	186,739		$	(7,724	)
Storage:
Throughput (barrels/day)	315,616			788,963			(473,347		)
Throughput terminal revenues	$	63,932		$	88,307		$	(24,375	)
Storage terminal revenues	400,129			373,733			26,396
Total revenues	464,061			462,040			2,021
Operating expenses	199,525			206,883			(7,358		)
Depreciation and amortization expense	95,405			88,661			6,744
Segment operating income	$	169,131		$	166,496		$	2,635
Fuels Marketing:
Product sales and other revenue	$	524,083		$	476,499		$	47,584
Cost of product sales	497,722			450,705			47,017
Gross margin	26,361			25,794			567
Operating expenses	22,464			25,512			(3,048		)
Segment operating income	$	3,897		$	282		$	3,615
Consolidation and Intersegment Eliminations:
Revenues	$	(10,066	)	$	(16,543	)	$	6,477
Cost of product sales	(7,359		)	(8,969		)	1,610
Operating expenses	(2,707		)	(7,574		)	4,867
Total	$	—		$	—		$	—
Consolidated Information:
Revenues	$	1,363,484		$	1,284,925		$	78,559
Cost of product sales	490,363			441,736			48,627
Operating expenses	334,016			335,315			(1,299		)
Depreciation and amortization expense	187,062			154,357			32,705
Segment operating income	352,043			353,517			(1,474		)
General and administrative expenses	83,202			73,399			9,803
Other depreciation and amortization expense	6,581			6,382			199
Consolidated operating income	$	262,260		$	273,736		$	(11,476	)

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Pipeline

Total revenues increased $22.5 million and total throughputs increased 143,671 barrels per day for the nine months ended September 30, 2017, compared to the nine months ended September 30, 2016, primarily due to:


•	an increase in revenues of $25.1 million and an increase in throughputs of 151,481 barrels per day from our recently acquired Permian Crude System;


•	an increase in revenues of $6.7 million and an increase in throughputs of 5,130 barrels per day due to maintenance downtime in 2016 on a portion of the Ammonia Pipeline, as well as operational issues in 2016 at certain plants served by the pipeline;

•

an increase in revenues of $2.6 million, despite a decrease in throughputs of 3,247 barrels per day, on our East Pipeline due to the completion of various storage projects along the pipeline, as well as an increase in long-haul deliveries resulting in higher average tariffs. A turnaround and operational issues at the refineries served by the East Pipeline in the third quarter of 2017 contributed to the decrease in throughputs; and


•	an increase in revenues of $2.1 million and an increase in throughputs of 21,781 barrels per day due to increased production at the refinery served by the Ardmore System in 2017, as well as a result of a turnaround and operational issues at the refinery in 2016.

These increases were partially offset by a decrease in revenues of $7.2 million and a decrease in throughputs of 10,115 barrels per day due to a turnaround in the second quarter of 2017 at the refinery served by the North Pipeline. Revenues decreased $6.1 million due to a decrease in throughputs of 24,078 barrels per day on our Eagle Ford System mainly due to reduced production in this sustained low crude oil price environment.

Operating expenses increased $4.2 million for the nine months ended September 30, 2017, compared to the nine months ended September 30, 2016. Operating expenses increased $6.3 million as a result of our acquisition of the Permian Crude System, which was partially offset by a decrease of $2.0 million from product imbalances on the East Pipeline.

Depreciation and amortization expense increased $26.0 million for the nine months ended September 30, 2017, compared to the nine months ended September 30, 2016, due to our acquisition of the Permian Crude System and the completion of various pipeline projects.

Storage

Beginning January 1, 2017, our agreements for our refinery crude storage tanks at Corpus Christi, TX, Texas City, TX and Benicia, CA changed from throughput-based to storage-based. Excluding the effect from the change to these agreements, throughput terminal revenues would have increased $6.0 million and throughputs would have decreased 2,207 barrels per day for the nine months ended September 30, 2017, compared to the nine months ended September 30, 2016. Throughput terminal revenues increased at our Corpus Christi North Beach terminal by $11.3 million due to an increase in throughputs of 15,898 barrels per day, mainly resulting from the Martin Terminal Acquisition. The benefit of the Martin Terminal Acquisition was partially offset by lower revenues and throughputs resulting from a decrease in Eagle Ford Shale crude oil being shipped to Corpus Christi. Revenues increased by $0.3 million and throughputs increased 17,128 barrels per day at our McKee System terminals mainly due to new customer contracts, partially offset by lower additive revenues in 2017. These increases in revenues and throughputs were partially offset by decreased revenues of $5.0 million and decreased throughputs of 32,612 barrels per day at our Paulsboro, NJ terminal as a customer diverted barrels to other terminals.

Storage terminal revenues would have decreased $2.9 million for the nine months ended September 30, 2017, compared to the nine months ended September 30, 2016, excluding the effect of the change to the refinery storage tank agreements described above. Domestic throughput and associated handling fees decreased $5.0 million, mainly at our St. James, LA terminal due to reduced unit train activity and at our Texas City, TX terminal as a result of the exit from our heavy fuels trading operations. Domestic reimbursable revenues decreased $2.5 million, mainly at our Texas City, TX terminal. These decreases were partially offset by an increase in revenues of $4.3 million due to new customer contracts and rate escalations, primarily at our West Coast, North East and St. James, LA terminals.

Storage terminal revenues also increased $5.5 million at our St. Eustatius terminal, mainly due to new customer contracts and rate escalations, partially offset by decreased lower throughput and associated handling fees as a result of the shutdown of the terminal and damage caused by hurricane activity in the third quarter of 2017. This increase was partially offset by a decrease in revenues of $4.6 million at our Point Tupper terminal, mainly resulting from a decrease in customer base, tanks out of service and lower reimbursable revenues.

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Operating expenses decreased $7.4 million for the nine months ended September 30, 2017, compared to the nine months ended September 30, 2016, primarily due to:


•	a decrease of $5.1 million in reimbursable expenses, mainly at our Texas City, TX and Point Tupper terminals, consistent with the decrease in reimbursable revenues;


•	a decrease of $4.5 million in maintenance and regulatory expenses primarily at our North East and Point Tupper terminals;


•	a decrease of $2.4 million in contractor services, mainly at our St. James, LA terminal as a result of reduced unit train activity; and


•	a decrease of $2.3 million in compensation expenses resulting from changes in our revenue agreements for our crude refinery storage tanks.

These decreases were partially offset by increased operating expenses of $6.5 million as a result of the Martin Terminal Acquisition.

Depreciation and amortization expense increased $6.7 million for the nine months ended September 30, 2017, compared to the nine months ended September 30, 2016, as a result of the Martin Terminal Acquisition and the completion of various storage projects.

Fuels Marketing

Segment operating income increased $3.6 million for the nine months ended September 30, 2017, compared to the nine months ended September 30, 2016, primarily due to a reduction in losses of $5.8 million from our heavy fuels trading operations following our exit of that business in 2017. Segment operating income from our bunker fuel operations decreased $3.4 million, mainly at our St. Eustatius terminal, resulting from lower gross margins and the temporary shutdown of the terminal caused by hurricane activity in the third quarter of 2017.

Consolidation and Intersegment Eliminations

General

General and administrative expenses increased $9.8 million for the nine months ended September 30, 2017, compared to the nine months ended September 30, 2016, primarily due to transaction costs related to the Navigator Acquisition.

Interest expense, net increased $23.9 million for the nine months ended September 30, 2017, compared to the nine months ended September 30, 2016, mainly due to the issuance of $550.0 million of 5.625% senior notes in April 2017 and as a result of fees for a bridge loan commitment to potentially assist with the financing of the Navigator Acquisition. We did not enter into or borrow under the bridge loan. Interest expense also increased as a result of lower interest income due to the termination of the Axeon Term Loan in February 2017. Please refer to Note 6 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for a discussion of the Axeon Term Loan and related credit support.

For the nine months ended September 30, 2017, we recognized other expense, net of $4.9 million mainly due to property damage at our St. Eustatius terminal resulting from hurricane activity in the third quarter of 2017.

Income tax expense decreased $2.0 million for the nine months ended September 30, 2017, compared to the nine months ended September 30, 2016, primarily due to a reduction in withholding taxes related to certain of our foreign subsidiaries.

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TRENDS AND OUTLOOK

As a master limited partnership, our core business strategy is to build long-term unitholder value through stable, consistent growth: to that end, we provide a broad array of logistical solution services to a diverse customer base in sectors across the energy industry with our portfolio of assets positioned in geographic markets around the globe, under primarily fee-based, long-term contractual arrangements. This strategy is intended to mitigate the impact of negative market conditions on our results and position us for the financial health necessary to grow as market conditions improve.

We believe that the fact that we provide both storage and pipeline services, for crude and refined products, to customers across the country and around the world, offers some insulation from the impact of commodity market price fluctuations on our results of operations. Since higher crude oil prices have tended to benefit our producer customers, high prices have also correlated with increased demand for our crude oil pipeline services. On the other hand, lower crude oil prices, when coupled with an industry expectation of higher prices in the future, or a contango market, has historically correlated with increased demand from trading companies for our storage services. In the locations at which our assets are integrated physically with the refineries the assets serve, we believe the results generated by those assets depend to a greater degree on each refinery’s continuing need to receive, store and transport the crude and refined products than on crude or refined product prices.

The Navigator Acquisition broadened our geographic footprint and marked our entry into the Permian Basin, one of the fastest-growing basins in the United States. The Permian Basin currently represents approximately forty percent of all onshore rig activity in the United States, and rig count growth in the Permian continues to outpace all other domestic shale plays. Our Permian Crude System is located in the most economic and highest growth counties in the basin, with some of the lowest break-even values in the United States, and offers our customers access to multiple downstream end-markets. We believe this system provides a strong growth platform in the most prolific basin in the United States. While the addition of the Permian Crude System to our asset portfolio could increase the impact of crude oil prices on our results of operations, we believe that our contracts, many of which are long-term, take-or-pay arrangements for committed storage or throughput capacity, should continue to help to blunt the impact of volatility of crude oil prices on our results of operations.

At the time of the Navigator Acquisition in May, we anticipated that our issuance of common units, senior notes and preferred units to fund the purchase price would increase our ongoing costs of funding our quarterly distribution, as well as our interest expense, but we made the decision to move forward because we believed, and continue to believe, that the Permian Crude System’s future growth will outweigh those costs in the long run.

The Permian Basin and our Permian Crude System have been growing since the acquisition, and we expect that growth to continue, even in a continued low price environment. In contrast, during 2017, our pipeline systems and storage assets outside of the Permian Basin (collectively, our Base Business) have been faced with several unanticipated challenges, on top of the continuing burden of the third year of sustained low crude prices. In September, hurricanes caused damage in the Gulf and significant destruction in the Caribbean. While we successfully prevented severe damage from Hurricane Harvey’s heavy rainfall to our six affected Gulf Coast facilities, Hurricane Irma passed almost directly over our facility at St. Eustatius, which sustained substantial damage inflicted by the storm’s 146-mph winds and 30-foot seas. The facility, which will be fully operational by mid-December, resumed some operations within weeks of the storm, but the repairs will continue into 2018 and beyond. On top of the unanticipated costs of the hurricane damage, our Base Business has also faced significant unanticipated and unplanned turnarounds and downtime at our customers’ refineries in 2017. Further, in the course of our ongoing pipeline integrity program, we identified a 50-mile segment of our ammonia pipeline that we must replace over the next five years. Due to the fact that completing the large, unanticipated reliability project in two years will reduce our overall cost, we plan to complete this project by the end of 2018.

Beyond the challenges to our Base Business that have arisen in 2017, if this current low crude price cycle continues in 2018, our pipeline segment could suffer from decreased throughput in our Base Business pipeline systems. For example, our current committed customers on our South Texas Crude System may decline to renew their commitments as those expire over the next few years and may ship only at lower rates. If backwardation continues into next year, our storage segment results could also decline, due to downward pressure on rates and contract renewals driven by lower demand for capacity, at our St. James terminal and at other locations.

Our outlook for the partnership, both overall and for any of our segments, may change, as we base our expectations on our continuing evaluation of a number of factors, many of which are outside our control. These factors include, but are not limited to, the state of the economy and the capital markets, changes to our customers’ refinery maintenance schedules and unplanned refinery downtime, crude oil prices, the supply of and demand for crude oil, refined products and anhydrous ammonia, demand for our transportation and storage services and changes in laws or regulations affecting our assets.

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LIQUIDITY AND CAPITAL RESOURCES

Overview

Our primary cash requirements are for distributions to our partners, debt service, capital expenditures, acquisitions and operating expenses. Our partnership agreement requires that we distribute all “Available Cash” to our common limited partners and general partner each quarter, and this term is defined in the partnership agreement generally as cash on hand at the end of the quarter, plus certain permitted borrowings made subsequent to the end of the quarter, less cash reserves determined by our board of directors.

Each year, our objective is to fund our total annual reliability capital expenditures and distribution requirements with our net cash provided by operating activities during that year. If we do not generate sufficient cash from operations to meet that objective, we utilize cash on hand or other sources of cash flow, which in the past have primarily included borrowings under our revolving credit agreement, sales of non-strategic assets and, to the extent necessary, funds raised through equity or debt offerings under our shelf registration statements. We have typically funded our strategic capital expenditures and acquisitions 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. Our risk factors in Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2016 describe the risks inherent to these sources of funding and the availability thereof.

During periods when our cash flow from operations is less than our distribution and reliability capital requirements, we may maintain our distribution level because we can utilize other sources of Available Cash, as provided in our partnership agreement, including borrowings under our revolving credit agreement and proceeds from the sales of assets. Our risk factors in Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2016 describe the risks inherent in our ability to maintain or grow our distribution.

For 2017, we expect an increase in total cash distributed to our unitholders and higher interest costs due to our issuances of debt and equity securities in 2017. See below for additional discussion of our April 2017 equity and debt issuances. However, we expect cash flows from operations, combined with a portion of the proceeds from the termination of the Axeon Term Loan of $110.0 million to exceed our distribution and reliability capital requirements for 2017.

Cash Flows for the Nine Months Ended September 30, 2017 and 2016

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



	Nine Months Ended September 30,
	2017			2016
	(Thousands of Dollars)
Net cash provided by (used in):
Operating activities	$	311,015		$	314,549
Investing activities	(1,557,041		)	(160,918		)
Financing activities	1,242,062			(243,235		)
Effect of foreign exchange rate changes on cash	1,637			3,404
Net decrease in cash and cash equivalents	$	(2,327	)	$	(86,200	)

Net cash provided by operating activities for the nine months ended September 30, 2017 was $311.0 million, compared to $314.5 million for the nine months ended September 30, 2016. Although net income decreased, the decrease was largely attributable to non-cash expenses. For the nine months ended September 30, 2017, net cash provided by operating activities and a portion of the proceeds from the termination of the Axeon Term Loan of $110.0 million were used to fund our distributions to unitholders and our general partner in the aggregate amount of $357.9 million and reliability capital expenditures of $30.2 million. Proceeds from our debt and equity issuances of approximately $1.5 billion were used to fund the purchase price of the Navigator Acquisition. Please refer to page 5 for our Consolidated Statements of Cash Flows.

For the nine months ended September 30, 2016, net cash provided by operating activities and cash on hand was used to fund our distributions to unitholders and our general partner in the aggregate amount of $294.2 million and reliability capital expenditures of $25.8 million. The proceeds from debt borrowings, net of repayments, proceeds from the issuance of common units and cash on hand were used to fund our strategic capital expenditures.

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Revolving Credit Agreement

The requirement not to exceed a maximum consolidated debt coverage ratio may limit the amount we can borrow under the Revolving Credit Agreement to an amount less than the total amount available for borrowing. As of September 30, 2017, our consolidated debt coverage ratio was 4.8x, and we had $863.8 million available for borrowing. Letters of credit issued under the Revolving Credit Agreement totaled $7.7 million as of September 30, 2017. Please refer to Note 4 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for a discussion on our revolving credit agreement.

Receivables Financing Agreement

NuStar Energy and NuStar Finance LLC (NuStar Finance), a special purpose entity and wholly owned subsidiary of NuStar Energy, are parties to a $125.0 million receivables financing agreement with third-party lenders (the Receivables Financing Agreement) and agreements with certain of NuStar Energy’s wholly owned subsidiaries (collectively with the Receivables Financing Agreement, the Securitization Program). On September 20, 2017, the Securitization Program was amended to add certain of NuStar Energy’s wholly owned subsidiaries resulting from the Navigator Acquisition and to extend the Securitization Program’s scheduled termination date from June 15, 2018 to September 20, 2020, with the option to renew for additional 364-day periods thereafter. The amount available for borrowing under the Receivables Financing Agreement is based on the availability of eligible receivables and other customary factors and conditions. Please refer to Note 4 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for additional discussion.

Other Sources of Liquidity

Other sources of liquidity as of September 30, 2017 consist of the following:


•	$365.4 million in revenue bonds pursuant to the Gulf Opportunity Zone Act of 2005 (the GoZone Bonds), with $42.5 million remaining in trust as of September 30, 2017, supported by $370.2 million in letters of credit; and


•	two short-term line of credit agreements with an uncommitted borrowing capacity of up to $85.0 million, with $68.0 million of borrowings outstanding as of September 30, 2017.

We are also a party to a $100.0 million uncommitted letter of credit agreement, which provides for standby letters of credit or guarantees with a term of up to one year (LOC Agreement). As of September 30, 2017, we had no letters of credit issued under the LOC Agreement. Please refer to Note 4 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for a discussion of certain of our debt agreements.

Issuance of Common Units

On April 18, 2017, we issued 14,375,000 common units representing limited partner interests at a price of $46.35 per unit. We used the net proceeds from this offering of $657.5 million, including a contribution of $13.6 million from our general partner to maintain its 2% general partner interest, to fund a portion of the purchase price for the Navigator Acquisition. Beginning with the distribution earned for the second quarter of 2017, our general partner will not receive incentive distributions with respect to these common units. Our general partner amended and restated our partnership agreement to waive up to an aggregate $22.0 million of the quarterly incentive distributions to our general partner for any NS common units issued from the date of the Acquisition Agreement (other than those attributable to NS common units issued under any equity compensation plan) for ten consecutive quarters. Please refer to Note 10 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for further discussion.

Issuance of Series B Preferred Units

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percentage of the $25.00 liquidation preference equal to an annual floating rate of the three-month LIBOR plus a spread of 5.643%. Please refer to Note 10 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for further discussion.

Issuance of 5.625% Senior Notes

Capital Requirements

Our operations require significant investments to maintain, upgrade or enhance the operating capacity of our existing assets. Our capital expenditures consist of:


•	strategic capital expenditures, such as those to expand or upgrade the operating capacity, increase efficiency or increase the earnings potential of existing assets, whether through construction or acquisition, as well as certain capital expenditures related to support functions; and


•	reliability capital expenditures, such as those required to maintain the existing operating capacity of existing assets or extend their useful lives, as well as those required to maintain equipment reliability and safety.

The following table summarizes our capital expenditures, and the amount we expect to spend for 2017:



	Strategic Capital Expenditures		Reliability Capital Expenditures		Total
	(Thousands of Dollars)
For the nine months ended September 30:
2017	$	190,417	$	30,200	$	220,617
2016	$	119,580	$	25,834	$	145,414

Expected for the year ended December 31, 2017 (a)	$ 360,000 - 380,000		$ 50,000 - 70,000		$ 410,000 - 450,000

(a) Excludes the purchase price of the Navigator Acquisition.

We continue to evaluate our capital spending forecast and make changes as economic conditions warrant, and our actual capital expenditures for 2017 may increase or decrease from our current projections. We believe we can fund our currently expected capital expenditures with cash on hand, combined with the sources of liquidity previously described. Our internal growth projects can be accelerated or scaled back depending on market conditions or customer demand.

Working Capital Requirements

Working capital requirements, particularly in our fuels marketing segment, may vary with the seasonality of demand and the volatility of commodity prices for the products we market. This seasonality in demand and the volatility of commodity prices affect our accounts receivable and accounts payable balances, which vary depending on the timing of payments.

Axeon Term Loan and Credit Support

On February 22, 2017, we settled and terminated the $190.0 million Axeon Term Loan, pursuant to which we also provided credit support, such as guarantees, letters of credit and cash collateral, as applicable, of up to $125.0 million to Axeon. We received $110.0 million in settlement of the Axeon Term Loan, and our obligation to provide ongoing credit support to Axeon ceased. Please refer to Note 6 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for a discussion of the Axeon Term Loan and credit support.

Defined Benefit Plans Funding

In September 2017, we contributed $11.0 million to our pension plans.

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Distributions



	Three Months Ended September 30,				Nine Months Ended September 30,
	2017		2016		2017		2016
	(Thousands of Dollars, Except Per Unit Data)
General partner interest	$	2,302	$	1,976	$	6,947	$	5,898
General partner incentive distribution	10,912		10,890		34,736		32,500
Total general partner distribution	13,214		12,866		41,683		38,398
Common limited partners’ distribution	101,870		85,943		305,652		256,513
Total cash distributions	$	115,084	$	98,809	$	347,335	$	294,911

Cash distributions per unit applicable to common limited partners	$	1.095	$	1.095	$	3.285	$	3.285

Distribution payments to our general partner and common limited partners are made within 45 days after the end of each quarter as of a record date that is set after the end of each quarter. The following table summarizes information related to our quarterly cash distributions to our general partner and common limited partners:



Quarter Ended	Cash Distributions Per Unit		Total Cash Distributions		Record Date	Payment Date
			(Thousands of Dollars)
September 30, 2017 (a)	$	1.095	$	115,084	November 9, 2017	November 14, 2017
June 30, 2017	$	1.095	$	115,083	August 7, 2017	August 11, 2017
March 31, 2017	$	1.095	$	117,168	May 8, 2017	May 12, 2017
December 31, 2016	$	1.095	$	98,971	February 8, 2017	February 13, 2017


(a)	The distribution was announced on October 18, 2017.

Preferred Units. The following table summarizes information related to our quarterly cash distributions on our Series A and Series B Preferred Units:



Period	Cash Distributions Per Unit		Total Cash Distributions		Record Date	Payment Date
			(Thousands of Dollars)
Series A Preferred Units:
September 15, 2017 - December 14, 2017 (a)	$	0.53125	$	4,813	December 1, 2017	December 15, 2017
June 15, 2017 - September 14, 2017	$	0.53125	$	4,813	September 1, 2017	September 15, 2017
March 15, 2017 - June 14, 2017	$	0.53125	$	4,813	June 1, 2017	June 15, 2017
November 25, 2016 - March 14, 2017	$	0.64930556	$	5,883	March 1, 2017	March 15, 2017

Series B Preferred Units:
September 15, 2017 to December 14, 2017 (a)	$	0.47657	$	7,339	December 1, 2017	December 15, 2017
April 28, 2017 - September 14, 2017	$	0.725434028	$	11,172	September 1, 2017	September 15, 2017


(a)	The distribution was announced on October 18, 2017.

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Debt Obligations

As of September 30, 2017, we were a party to the following debt agreements:


•	Revolving Credit Agreement due October 29, 2020, with $878.4 million of borrowings outstanding as of September 30, 2017;

•

7.65% senior notes due April 15, 2018 with a face value of $350.0 million; 4.80% senior notes due September 1, 2020 with a face value of $450.0 million; 6.75% senior notes due February 1, 2021 with a face value of $300.0 million; 4.75% senior notes due February 1, 2022 with a face value of $250.0 million; 5.625% senior notes due April 28, 2027 with a face value of $550.0 million; and 7.625% subordinated notes due January 15, 2043 with a face value of $402.5 million.


•	$365.4 million in GoZone Bonds due from 2038 to 2041;


•	Line of credit agreements with $68.0 million of borrowings outstanding as of September 30, 2017; and


•	Receivables Financing Agreement due September 20, 2020, with $46.1 million of borrowings outstanding as of September 30, 2017.

Management believes that, as of September 30, 2017, we are in compliance with the ratios and covenants contained in our debt instruments. A default under certain of our debt agreements would be considered an event of default under other of our debt instruments. Please refer to Note 4 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for a discussion of certain of our debt agreements.

Credit Ratings

The following table reflects the current outlook and ratings that have been assigned to our debt:



	Standard & Poor’s Ratings Services	Moody’s Investor Service Inc.	Fitch, Inc.

Ratings	BB+	Ba1	BB
Outlook	Stable	Negative	Stable

Following the announcement of the Navigator Acquisition, Standard & Poor’s Ratings Services and Fitch, Inc. affirmed their ratings and outlook, and Moody’s Investor Service Inc. (Moody’s) announced that it was reviewing NuStar Energy and NuStar Logistics for a downgrade. Following its review in the second quarter of 2017, Moody’s affirmed its rating and changed its outlook to “Negative.” The change in outlook had no impact on the interest rates payable on the 7.65% senior notes due 2018 or the revolving credit agreement, which are subject to adjustment if our debt rating is downgraded (or upgraded) by certain credit rating agencies, but are not impacted by a change in the outlook.

Interest Rate Swaps

As of September 30, 2017 and December 31, 2016, we were a party to forward-starting interest rate swap agreements for the purpose of hedging interest rate risk. As of September 30, 2017 and December 31, 2016, the aggregate notional amount of these forward-starting interest rate swaps was $600.0 million. 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

Our operations are subject to extensive federal, state and local environmental laws and regulations, in the U.S. and in the other countries in which we operate, including those relating to the discharge of materials into the environment, waste management, remediation, the characteristics and composition of fuels and pollution prevention measures, among others. Our operations are also subject to extensive federal, state and local health and safety laws and regulations, including those relating to worker and pipeline safety, pipeline integrity and operator qualifications. Because more stringent environmental and safety laws and regulations are continuously being enacted or proposed, the level of expenditures required for environmental, health and safety matters is expected to increase in the future.

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.”

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RELATED PARTY TRANSACTIONS

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

CRITICAL ACCOUNTING POLICIES

The preparation of financial statements in accordance with U.S. 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, 2016.

NEW ACCOUNTING PRONOUNCEMENTS

Please refer to Note 2 of the Condensed Notes to Consolidated Financial Statements in Item 1. “Financial Statements” for a discussion of new accounting pronouncements.

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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 forward-starting interest rate swap agreements to lock in the rate on the interest payments related to forecasted debt issuances. Borrowings under our variable-rate debt expose us to increases in interest rates.

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. The following tables present principal cash flows and related weighted-average interest rates by expected maturity dates for our long-term debt:



	September 30, 2017
	Expected Maturity Dates
	2017		2018			2019		2020			2021			There- after			Total			Fair Value
	(Thousands of Dollars, Except Interest Rates)
Long-term Debt:
Fixed-rate	$	—	$	350,000		$	—	$	450,000		$	300,000		$	1,202,500		$	2,302,500		$	2,403,835
Weighted-average interest rate	—		8.2		%	—		4.8		%	6.8		%	6.1		%	6.2		%
Variable-rate	$	—	$	—		$	—	$	924,539		$	—		$	365,440		$	1,289,979		$	1,291,042
Weighted-average interest rate	—		—			—		2.8		%	—			1.0		%	2.3		%



	December 31, 2016
	Expected Maturity Dates
	2017		2018			2019			2020			2021			There- after			Total			Fair Value
	(Thousands of Dollars, Except Interest Rates)
Long-term Debt:
Fixed-rate	$	—	$	350,000		$	—		$	450,000		$	300,000		$	652,500		$	1,752,500		$	1,821,261
Weighted-average interest rate	—		8.2		%	—			4.8		%	6.8		%	6.5		%	6.4		%
Variable-rate	$	—	$	58,400		$	838,992		$	—		$	—		$	365,440		$	1,262,832		$	1,263,501
Weighted-average interest rate	—		1.6		%	2.5		%	—			—			0.7		%	1.9		%

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



Notional Amount					Weighted-Average Fixed Rate				Fair Value
September 30, 2017		December 31, 2016		Period of Hedge	September 30, 2017		December 31, 2016		September 30, 2017			December 31, 2016
(Thousands of Dollars)									(Thousands of Dollars)
$	350,000	$	350,000	04/2018 - 04/2028	2.6	%	2.6	%	$	(7,280	)	$	(1,333	)
250,000		250,000		09/2020 - 09/2030	2.8	%	2.8	%	(4,043		)	15
$	600,000	$	600,000		2.7	%	2.7	%	$	(11,323	)	$	(1,318	)

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Commodity Price Risk

Since the operations of our fuels marketing segment expose us to commodity price risk, we use derivative instruments to attempt to mitigate the effects 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 policies 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, as approved by our board of directors.

We record commodity derivative instruments in the consolidated balance sheets 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 that have associated underlying physical inventory but do not qualify for hedge accounting (Economic Hedges and Other Derivatives), we record the mark-to-market adjustments in “Cost of product sales.”

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 Statements in Item 1. “Financial Statements” for the volume and related fair value of all commodity contracts.



	September 30, 2017
	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)	4	$	76.62	N/A		$	(2	)
Futures – short:
(refined products)	15	N/A		$	77.21	$	18

Economic Hedges and Other Derivatives:
Futures – long:
(refined products)	7	$	76.62	N/A		$	(4	)
Futures – short:
(refined products)	12	N/A		$	76.91	$	11
Swaps – long:
(refined products)	254	$	48.38	N/A		$	(5	)
Swaps – short:
(refined products)	364	N/A		$	46.91	$	(499	)

Total fair value of open positions exposed to commodity price risk						$	(481	)

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	December 31, 2016
	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:
(crude oil and refined products)	47	$	55.53	N/A		$	2
Futures – short:
(crude oil and refined products)	107	N/A		$	58.79	$	(243	)
Swaps – long:
(refined products)	84	$	45.99	N/A		$	141
Swaps – short:
(refined products)	573	N/A		$	41.87	$	(3,322	)

Economic Hedges and Other Derivatives:
Futures – long:
(crude oil and refined products)	18	$	72.06	N/A		$	10
Futures – short:
(crude oil and refined products)	9	N/A		$	71.88	$	(7	)
Swaps – long:
(refined products)	869	$	42.20	N/A		$	4,737
Swaps – short:
(refined products)	874	N/A		$	41.40	$	(5,459	)
Forward purchase contracts:
(crude oil)	310	$	52.78	N/A		$	499
Forward sales contracts:
(crude oil)	310	N/A		$	52.76	$	(507	)

Total fair value of open positions exposed to commodity price risk						$	(4,149	)

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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, 2017.


(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 6.	Exhibits



Exhibit Number		Description

10.01		Maturity Extension Letter (Amendment No. 4) to Letter of Credit Agreement and Subsidiary Guaranty Agreement dated as of July 13, 2017 among NuStar Logistics, L.P., NuStar Energy L.P., the Lenders party thereto and The Bank of Tokyo-Mitsubishi UFJ, Ltd., as Issuing Bank and Administrative Agent (incorporated by reference to Exhibit 10.02 to NuStar Energy L.P.’s Quarterly Report on Form 10-Q for the quarter ended June 30, 2017 (File No. 001-16417))

*10.02		First Amendment to Amended and Restated Aircraft Time Sharing Agreement, dated as of August 18, 2017, between NuStar Logistics, L.P. and William E. Greehey

10.03		Second Amendment to Amended and Restated 5-Year Revolving Credit Agreement, dated as of August 22, 2017, among NuStar Logistics, L.P., NuStar Energy L.P., JPMorgan Chase Bank, N.A., as Administrative Agent, and the Lenders party thereto (incorporated by reference to Exhibit 10.01 to NuStar Energy L.P.’s Current Report on Form 8-K filed August 22, 2017 (File No. 001-16417))

10.04		Second Amendment to Purchase and Sale Agreement, dated as of September 20, 2017, by and among the Originators listed therein, NuStar Energy L.P., NuStar Finance LLC, Mizuho Bank, Ltd. and PNC Bank, National Association (incorporated by reference to Exhibit 10.01 to NuStar Energy L.P.’s Current Report on Form 8-K filed September 20, 2017 (File No. 001-16417))

10.05		Second Amendment to Receivables Financing Agreement, dated as of September 20, 2017, by and among NuStar Finance, LLC, as Borrower, NuStar Energy L.P., as initial Servicer, Mizuho Bank, Ltd. and PNC Bank, National Association (incorporated by reference to Exhibit 10.02 to NuStar Energy L.P.’s Current Report on Form 8-K filed September 20, 2017 (File No. 001-16417))

*12.01		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.INS		XBRL Instance Document

*101.SCH		XBRL Taxonomy Extension Schema Document

*101.CAL		XBRL Taxonomy Extension Calculation Linkbase Document

*101.DEF		XBRL Taxonomy Extension Definition Linkbase Document

*101.LAB		XBRL Taxonomy Extension Label Linkbase Document

*101.PRE		XBRL Taxonomy Extension Presentation Linkbase Document
*	Filed herewith.
**	Furnished herewith.

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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/ Bradley C. Barron
		Bradley C. Barron
		President and Chief Executive Officer
		November 8, 2017

By:		/s/ Thomas R. Shoaf
		Thomas R. Shoaf
		Executive Vice President and Chief Financial Officer
		November 8, 2017

By:		/s/ Jorge A. del Alamo
		Jorge A. del Alamo
		Senior Vice President and Controller
		November 8, 2017

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