Attached files
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| 8-K - 8-K - NuStar Energy L.P. | ns4q138-k.htm |
Exhibit 99.1
NuStar Energy Reports Highest Quarterly Coverage Ratio Since 3rd Quarter 2011
4th Quarter 2013 EPU and EBITDA Negatively Impacted by Non-Cash Charges
Corpus Dock Expansion to be Completed Earlier than Expected
Plans to Close on Divestiture of Remaining 50% Interest in Asphalt Joint Venture by end of February 2014
Oxy to Begin Transporting NGLs on Idled 12” Pipeline
SAN ANTONIO, February 5, 2014 - NuStar Energy L.P. (NYSE: NS) today announced fourth quarter 2013 distributable cash flow from continuing operations available to limited partners was $75.3 million, or $0.97 per unit, compared to 2012 fourth quarter distributable cash flow from continuing operations available to limited partners of $60.5 million, or $0.78 per unit. For the year ended December 31, 2013, distributable cash flow from continuing operations available to limited partners was $257.8 million, or $3.31 per unit, higher than the $210.8 million, or $2.89 per unit earned in 2012.
“2013 was a major turning point for NuStar as we took steps to significantly reduce our exposure to margin-based operations and continued to invest in the growth of our more stable pipelines and terminals business,” said Brad Barron, President and Chief Executive Officer of NuStar Energy L.P. and NuStar GP Holdings, LLC. “We’re starting to see the results of this strategic redirection as the first quarter is off to a good start.
“We’re excited about several important initiatives being announced today that are expected to help improve our earnings in 2014 and beyond. We have made tremendous progress on the expansion of our Corpus Christi dock, which is now expected to be in service later this month - several months ahead of schedule. We completed construction on our second rail-car offloading facility at our St. James terminal. We forged an agreement with Lindsay Goldberg to divest our remaining 50% interest in our Asphalt Joint Venture, and we completed an agreement with Oxy to re-activate our idled 12” pipeline between Mont Belvieu and Corpus Christi.
“We have made a lot of progress over the past couple of months, and we’re going to keep up the pace as everyone is focused on our goal of returning to one-to-one coverage of our distribution. Largely as a result of the improved adjusted EBITDA results in all three of our segments in 2013, NuStar’s fourth quarter distributable cash flow from continuing operations available to limited partners covered the distribution to the limited partners by 0.89 times, the highest quarterly coverage ratio since the third quarter of 2011. Based on our current projections, we expect to start exceeding a one-times coverage ratio in the second half of 2014 and for the full year 2014,” said Barron.
Fourth Quarter and Full Year Earnings Results
As a result of some of the non-cash charges described below, fourth quarter earnings before interest, taxes, depreciation and amortization (EBITDA) from continuing operations was negative $192.3 million compared to fourth quarter 2012 EBITDA of $81.8 million. For the year ended December 31, 2013, EBITDA from continuing operations was $127.2 million, higher than the $107.6 million in 2012.
NuStar Energy L.P. reported a fourth quarter net loss applicable to limited partners of $368.3 million, or $4.73 per unit, compared to a net loss applicable to limited partners of $21.2 million, or $0.27 per unit, reported in the fourth quarter of 2012. Without certain adjustments in the fourth quarters of both years, as described below, the fourth quarter of 2013 would have generated adjusted net income applicable to limited partners of $16.6 million, or $0.21 per unit, compared to the fourth quarter 2012 adjusted net income applicable to limited partners of $19.5 million, or $0.25 per unit.
For the year ended December 31, 2013, the company reported a net loss applicable to limited partners of $311.5 million, or $4.00 per unit, compared to a net loss applicable to limited partners of $263.3 million, or $3.61 per unit, in 2012. Without certain adjustments in both years, as described below, adjusted net income applicable to limited partners would have been $58.8 million, or $0.75 per unit, compared to 2012 adjusted net income applicable to limited partners of $53.6 million, or $0.73 per unit.
As previously announced on January 30, 2014, the fourth quarter 2013 distribution of $1.095 per unit will be paid on February 14, 2014 to holders of record as of February 10, 2014.
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“Absent the impact of several non-cash adjustments, our fourth quarter 2013 results in both our fee-based pipeline and storage segments were higher than last year’s fourth quarter,” said Barron. “The completion of several internal growth projects in these segments contributed to the improved fourth quarter results.”
“I am also happy to note that our fuels marketing segment results were higher than last year’s fourth quarter as well.”
Fourth Quarter and Full Year Adjustments
Fourth quarter 2013 results include $403.6 million, or $4.94 per unit, of adjustments, primarily non-cash charges associated with the write-down of asset values and the value of goodwill assigned to several of the company’s terminal facilities. Fourth quarter 2012 results included $41.5 million, or $0.52 per unit, of expense items related primarily to hedge losses recorded following NuStar’s decision to sell the San Antonio refinery in December 2012, as well as a handful of cancelled capital projects.
Full year 2013 results include $388.8 million, or $4.75 per unit, of adjustments, comprised of the fourth quarter 2013 non-cash adjustments mentioned previously and other adjustment items. Full year 2012 results included $323.4 million, or $4.34 per unit of adjustments, which included the fourth quarter 2012 adjustments mentioned previously, and $281.9 million, or $3.82 per unit, of expense items resulting from deconsolidating the asphalt joint venture in September 2012 and other adjustment items.
Internal Growth Project Update
In November, the company completed the construction of a second rail-car offloading facility at its St. James terminal in Louisiana. NuStar now has two rail-car facilities in operation at the terminal with a total offloading capacity of 100,000 to 200,000 barrels per day.
The construction of a new private dock at NuStar’s Corpus Christi North Beach terminal should be completed by the end of February 2014, far earlier than anticipated. The initial estimate for the completion of the dock was the second quarter of 2014. This new dock will more than double the current loading capacity of approximately 125,000 barrels per day and will allow NuStar to handle all the new volume associated with the Phase 1 and Phase 2 expansions of the South Texas Crude Oil Pipeline expansion, as well as additional volumes shipped to Corpus Christi.
Divestiture of 50% Interest in Asphalt Joint Venture
NuStar has entered into an agreement with an affiliate of Lindsay Goldberg LLC, a private investment firm, to divest its 50% voting interest in an asphalt joint venture that owns a refinery located in Paulsboro, New Jersey, a terminal located in Savannah, Georgia and the related working capital. Closing for the transaction is expected to be completed no later than February 28, 2014.
After the transaction is closed, a $250 million seven-year revolving credit facility between NuStar Logistics and the joint venture will be immediately converted to a $175 million term loan, dropping to a $150 million term loan six months after closing. The transaction calls for the loan to be paid off in full no later than September 2019. NuStar Logistics will continue to provide up to $150 million of credit support to the asphalt business, in the form of guarantees and letters of credit. This commitment begins declining two years after closing and terminates in September 2019.
Reactivation of Mont Belvieu to Corpus Christi 12” Pipeline
NuStar and Occidental Petroleum Corporation (Oxy) have entered into a long-term agreement in which Oxy will ship natural gas liquids (NGLs) on NuStar’s currently idled, 200-mile, 12-inch pipeline between Mont Belvieu and Corpus Christi, Texas. Oxy will use a majority of the line’s 110,000 barrel per day capacity and NuStar will continue to market any remaining capacity to third parties. The line will begin generating distributable cash flow in the second quarter of 2014 and is expected to be placed into full NGL service in the second quarter of 2015. Once the line is in full service, it is expected to generate approximately $23 million per year of incremental EBITDA.
2014 Earnings Guidance
“First quarter 2014 EBITDA results for our pipeline and fuels marketing segments should be higher than last year’s first quarter due to the benefit from our Eagle Ford shale internal growth projects and improved results in our bunkering operations,” said Barron. “However, our first quarter storage segment results are expected to be lower than last year primarily due to reduced LLS to WTI profit-sharing benefits at our St. James, Louisiana terminal.”
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Commenting on guidance for the full year 2014, Barron said, “Our pipeline segment EBITDA should be $40 to $60 million higher than 2013 while our storage segment EBITDA should be comparable to 2013. We expect our fuels marketing segment to generate EBITDA in the range of $10 to $30 million. Based on these projections, we expect our coverage ratio to start exceeding one-times in the second half of 2014 and for the full year 2014.”
With regard to capital spending projections for 2014, Barron went on to say, “We plan to spend $370 to $390 million on internal growth projects during 2014. Most of this spending should be focused on projects in our pipeline segment. 2014 reliability capital spending is expected to be in the range of $35 to $45 million.”
Fourth Quarter Earnings Conference Call Details
A conference call with management is scheduled for 9:00 a.m. CT today, February 5, 2014, to discuss the financial and operational results for the fourth quarter of 2013. Investors interested in listening to the presentation may call 800/622-7620, passcode 32985588. International callers may access the presentation by dialing 706/645-0327, passcode 32985588. The company intends to have a playback available following the presentation, which may be accessed by calling 800/585-8367, passcode 32985588. International callers may access the playback by calling 404/537-3406, passcode 32985588. A live broadcast of the conference call will also be available on the company’s Web site at www.nustarenergy.com.
NuStar Energy L.P., a publicly traded master limited partnership based in San Antonio, is one of the largest independent liquids terminal and pipeline operators in the nation. NuStar currently has 8,643 miles of pipeline; 89 terminal and storage facilities that store and distribute crude oil, refined products and specialty liquids; and 50% ownership in a joint venture that owns a terminal and an asphalt refinery with a throughput capacity of 74,000 barrels per day. The partnership’s combined system has approximately 97 million barrels of storage capacity, and NuStar has operations in the United States, Canada, Mexico, the Netherlands, including St. Eustatius in the Caribbean, the United Kingdom and Turkey. For more information, visit NuStar Energy L.P.’s Web site at www.nustarenergy.com.
This release serves as qualified notice to nominees under Treasury Regulation Sections 1.1446-4(b)(4) and (d). Please note that 100% of NuStar’s distributions to foreign investors are attributable to income that is effectively connected with a United States trade or business. Accordingly, all of NuStar’s distributions to foreign investors are subject to federal income tax withholding at the highest effective tax rate for individuals and corporations, as applicable. Nominees, and not NuStar, are treated as the withholding agents responsible for withholding on the distributions received by them on behalf of foreign investors.
Cautionary Statement Regarding Forward-Looking Statements
This press release includes forward-looking statements regarding future events. All forward-looking statements are based on the partnership and company’s beliefs as well as assumptions made by and information currently available to the partnership and company. These statements reflect the partnership and company’s current views with respect to future events and are subject to various risks, uncertainties and assumptions. These risks, uncertainties and assumptions are discussed in NuStar Energy L.P. and NuStar GP Holdings, LLC’s 2012 annual reports on Form 10-K and subsequent filings with the Securities and Exchange Commission.
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NuStar Energy L.P. and Subsidiaries
Consolidated Financial Information
(Unaudited, Thousands of Dollars, Except Unit and Per Unit Data)
Three Months Ended December 31, | Year Ended December 31, | ||||||||||||||
2013 | 2012 | 2013 | 2012 | ||||||||||||
Statement of Income Data (Note 1): | |||||||||||||||
Revenues: | |||||||||||||||
Service revenues | $ | 237,216 | $ | 231,776 | $ | 938,138 | $ | 870,157 | |||||||
Product sales | 548,171 | 751,114 | 2,525,594 | 5,075,579 | |||||||||||
Total revenues | 785,387 | 982,890 | 3,463,732 | 5,945,736 | |||||||||||
Costs and expenses: | |||||||||||||||
Cost of product sales | 525,760 | 718,208 | 2,453,997 | 4,930,174 | |||||||||||
Operating expenses | 112,463 | 136,859 | 454,396 | 526,145 | |||||||||||
General and administrative expenses | 25,108 | 29,502 | 91,086 | 104,756 | |||||||||||
Depreciation and amortization expense | 45,805 | 38,196 | 178,921 | 159,789 | |||||||||||
Goodwill impairment loss | 304,453 | — | 304,453 | 22,132 | |||||||||||
Asset impairment loss | — | — | — | 249,646 | |||||||||||
Gain on legal settlement | — | — | — | (28,738 | ) | ||||||||||
Total costs and expenses | 1,013,589 | 922,765 | 3,482,853 | 5,963,904 | |||||||||||
Operating (loss) income | (228,202 | ) | 60,125 | (19,121 | ) | (18,168 | ) | ||||||||
Equity in loss of joint ventures | (13,341 | ) | (13,194 | ) | (39,970 | ) | (9,378 | ) | |||||||
Interest expense, net | (34,270 | ) | (22,605 | ) | (127,119 | ) | (90,535 | ) | |||||||
Interest income from related party | 1,553 | 1,158 | 6,113 | 1,219 | |||||||||||
Other income (expense), net | 3,424 | (3,297 | ) | 7,341 | (24,689 | ) | |||||||||
(Loss) income from continuing operations before income tax expense | (270,836 | ) | 22,187 | (172,756 | ) | (141,551 | ) | ||||||||
Income tax expense | 4,666 | 3,295 | 12,753 | 24,450 | |||||||||||
(Loss) income from continuing operations | (275,502 | ) | 18,892 | (185,509 | ) | (166,001 | ) | ||||||||
Loss from discontinued operations, net of tax | (99,778 | ) | (29,915 | ) | (99,162 | ) | (61,236 | ) | |||||||
Net loss | $ | (375,280 | ) | $ | (11,023 | ) | $ | (284,671 | ) | $ | (227,237 | ) | |||
Net loss applicable to limited partners | $ | (368,327 | ) | $ | (21,212 | ) | $ | (311,516 | ) | $ | (263,325 | ) | |||
Net (loss) income per unit applicable to limited partners | |||||||||||||||
Continuing operations | $ | (3.60 | ) | $ | 0.10 | $ | (2.89 | ) | $ | (2.79 | ) | ||||
Discontinued operations | (1.13 | ) | (0.37 | ) | (1.11 | ) | (0.82 | ) | |||||||
Total | $ | (4.73 | ) | $ | (0.27 | ) | $ | (4.00 | ) | $ | (3.61 | ) | |||
Weighted-average limited partner units outstanding | 77,886,078 | 77,886,078 | 77,886,078 | 72,957,417 | |||||||||||
EBITDA from continuing operations (Note 2) | $ | (192,314 | ) | $ | 81,830 | $ | 127,171 | $ | 107,554 | ||||||
DCF from continuing operations (Note 2) | $ | 88,115 | $ | 73,314 | $ | 308,877 | $ | 259,488 | |||||||
December 31, | |||||||||||||||
2013 | 2012 | ||||||||||||||
Balance Sheet Data: | |||||||||||||||
Debt, including current portion (a) | $ | 2,655,553 | $ | 2,411,004 | |||||||||||
Partners’ equity (b) | 1,903,794 | 2,584,995 | |||||||||||||
Debt-to-capitalization ratio (a) / ((a)+(b)) | 58.2 | % | 48.3 | % | |||||||||||
NuStar Energy L.P. and Subsidiaries
Consolidated Financial Information - Continued
(Unaudited, Thousands of Dollars, Except Barrel Data)
Three Months Ended December 31, | Year Ended December 31, | ||||||||||||||
2013 | 2012 | 2013 | 2012 | ||||||||||||
Storage: | |||||||||||||||
Throughput (barrels/day) | 807,414 | 794,335 | 781,213 | 765,556 | |||||||||||
Throughput revenues | $ | 27,629 | $ | 27,933 | $ | 104,553 | $ | 95,612 | |||||||
Storage lease revenues | 105,956 | 117,480 | 451,996 | 482,454 | |||||||||||
Total revenues | 133,585 | 145,413 | 556,549 | 578,066 | |||||||||||
Operating expenses | 71,596 | 86,638 | 279,712 | 288,881 | |||||||||||
Depreciation and amortization expense | 24,439 | 22,437 | 99,868 | 88,217 | |||||||||||
Goodwill and asset impairment loss | 304,453 | — | 304,453 | 2,126 | |||||||||||
Segment operating (loss) income | $ | (266,903 | ) | $ | 36,338 | $ | (127,484 | ) | $ | 198,842 | |||||
Pipeline: | |||||||||||||||
Refined products pipelines throughput (barrels/day) | 514,975 | 520,796 | 487,021 | 498,321 | |||||||||||
Crude oil pipelines throughput (barrels/day) | 377,937 | 402,813 | 365,749 | 345,648 | |||||||||||
Total throughput (barrels/day) | 892,912 | 923,609 | 852,770 | 843,969 | |||||||||||
Throughput revenues | $ | 109,768 | $ | 95,517 | $ | 411,529 | $ | 340,455 | |||||||
Operating expenses | 31,769 | 33,775 | 134,365 | 128,987 | |||||||||||
Depreciation and amortization expense | 18,832 | 13,792 | 68,871 | 52,878 | |||||||||||
Segment operating income | $ | 59,167 | $ | 47,950 | $ | 208,293 | $ | 158,590 | |||||||
Fuels Marketing: | |||||||||||||||
Product sales | $ | 549,167 | $ | 752,022 | $ | 2,527,698 | $ | 5,086,383 | |||||||
Cost of product sales | 530,197 | 725,549 | 2,474,612 | 4,957,100 | |||||||||||
Gross margin | 18,970 | 26,473 | 53,086 | 129,283 | |||||||||||
Operating expenses | 11,849 | 20,457 | 53,185 | 148,458 | |||||||||||
Depreciation and amortization expense | 7 | 18 | 27 | 11,253 | |||||||||||
Goodwill and asset impairment loss | — | — | — | 266,357 | |||||||||||
Segment operating income (loss) | $ | 7,114 | $ | 5,998 | $ | (126 | ) | $ | (296,785 | ) | |||||
Consolidation and Intersegment Eliminations: | |||||||||||||||
Revenues | $ | (7,133 | ) | $ | (10,062 | ) | $ | (32,044 | ) | $ | (59,168 | ) | |||
Cost of product sales | (4,437 | ) | (7,341 | ) | (20,615 | ) | (26,926 | ) | |||||||
Operating expenses | (2,751 | ) | (4,011 | ) | (12,866 | ) | (40,181 | ) | |||||||
Total | $ | 55 | $ | 1,290 | $ | 1,437 | $ | 7,939 | |||||||
Consolidated Information: | |||||||||||||||
Revenues | $ | 785,387 | $ | 982,890 | $ | 3,463,732 | $ | 5,945,736 | |||||||
Cost of product sales | 525,760 | 718,208 | 2,453,997 | 4,930,174 | |||||||||||
Operating expenses | 112,463 | 136,859 | 454,396 | 526,145 | |||||||||||
Depreciation and amortization expense | 43,278 | 36,247 | 168,766 | 152,348 | |||||||||||
Goodwill and asset impairment loss | 304,453 | — | 304,453 | 268,483 | |||||||||||
Segment operating (loss) income | (200,567 | ) | 91,576 | 82,120 | 68,586 | ||||||||||
General and administrative expenses | 25,108 | 29,502 | 91,086 | 104,756 | |||||||||||
Other depreciation and amortization expense | 2,527 | 1,949 | 10,155 | 7,441 | |||||||||||
Other asset impairment loss | — | — | — | 3,295 | |||||||||||
Gain on legal settlement | — | — | — | (28,738 | ) | ||||||||||
Consolidated operating (loss) income | $ | (228,202 | ) | $ | 60,125 | $ | (19,121 | ) | $ | (18,168 | ) | ||||
NuStar Energy L.P. and Subsidiaries
Consolidated Financial Information - Continued
(Unaudited, Thousands of Dollars, Except Per Unit Data)
Notes:
(1) | The results of operations for the following have been reported as discontinued operations for all periods presented: (i) the San Antonio Refinery and related assets and (ii) certain storage assets that were classified as “Assets held for sale” on the consolidated balance sheet as of December 31, 2013. |
(2) | NuStar Energy L.P. utilizes financial measures, earnings before interest, taxes, depreciation and amortization (EBITDA) from continuing operations, distributable cash flow (DCF) from continuing operations and DCF from continuing operations per unit, which are not defined in U.S. generally accepted accounting principles. Management uses these financial measures because they are widely accepted financial indicators used by investors to compare partnership performance. In addition, management believes that these measures provide investors an enhanced perspective of the operating performance of the partnership’s assets and the cash that the business is generating. None of EBITDA from continuing operations, DCF from continuing operations or DCF from continuing operations per unit are intended to represent cash flows from operations for the period, nor are they presented as an alternative to net income or income from continuing operations. They should not be considered in isolation or as substitutes for a measure of performance prepared in accordance with U.S. generally accepted accounting principles. |
The following is a reconciliation of (loss) income from continuing operations to EBITDA from continuing operations and DCF from continuing operations:
Three Months Ended December 31, | Year Ended December 31, | ||||||||||||||
2013 | 2012 | 2013 | 2012 | ||||||||||||
(Loss) income from continuing operations | $ | (275,502 | ) | $ | 18,892 | $ | (185,509 | ) | $ | (166,001 | ) | ||||
Plus interest expense, net and interest income from related party | 32,717 | 21,447 | 121,006 | 89,316 | |||||||||||
Plus income tax expense | 4,666 | 3,295 | 12,753 | 24,450 | |||||||||||
Plus depreciation and amortization expense | 45,805 | 38,196 | 178,921 | 159,789 | |||||||||||
EBITDA from continuing operations | (192,314 | ) | 81,830 | 127,171 | 107,554 | ||||||||||
Equity in loss of joint ventures | 13,341 | 13,194 | 39,970 | 9,378 | |||||||||||
Interest expense, net and interest income from related party | (32,717 | ) | (21,447 | ) | (121,006 | ) | (89,316 | ) | |||||||
Reliability capital expenditures | (11,600 | ) | (14,554 | ) | (39,939 | ) | (32,012 | ) | |||||||
Income tax expense | (4,666 | ) | (3,295 | ) | (12,753 | ) | (24,450 | ) | |||||||
Distributions from joint ventures | 2,169 | — | 7,956 | 6,364 | |||||||||||
Other items (a) | 315,718 | 13,304 | 311,675 | 287,981 | |||||||||||
Mark-to-market impact on hedge transactions (b) | (1,816 | ) | 4,282 | (4,197 | ) | (6,011 | ) | ||||||||
DCF from continuing operations | $ | 88,115 | $ | 73,314 | $ | 308,877 | $ | 259,488 | |||||||
Less DCF from continuing operations available to general partner | 12,766 | 12,766 | 51,064 | 48,728 | |||||||||||
DCF from continuing operations available to limited partners | $ | 75,349 | $ | 60,548 | $ | 257,813 | $ | 210,760 | |||||||
DCF from continuing operations per limited partner unit | $ | 0.97 | $ | 0.78 | $ | 3.31 | $ | 2.89 | |||||||
(a) | Other items for the three months and year ended December 31, 2013 mainly consist of (i) a non-cash goodwill impairment charge totaling $304.5 million and (ii) an increase in deferred revenue associated with throughput deficiency payments and construction reimbursements received in the period. |
Other items for the year ended December 31, 2012 consist of (i) $271.8 million of non-cash asset impairment charges mainly related to our asphalt operations, including fixed assets, goodwill and intangible assets, (ii) a $21.6 million loss associated with the sale of 50% of our asphalt operations on September 28, 2012, (iii) $13.3 million in costs written off mainly due to cancelled capital projects and (iv) an $18.7 million gain, net of tax, resulting from a legal settlement.
(b) | DCF from continuing operations excludes the impact of unrealized mark-to-market gains and losses that arise from valuing certain derivative contracts, as well as the associated hedged inventory. The gain or loss associated with these contracts is realized in DCF from continuing operations when the contracts are settled. |