Spectra Energy Reports Second Quarter 2015 Results

HOUSTON, Aug. 5, 2015 /PRNewswire/ --

Second Quarter Highlights:

• Ongoing EBITDA and distributable cash flow exceed prior year quarter
• EBITDA at Spectra Energy Partners segment up 28%
• $600 million in expansion projects placed into service while project backlog – underpinned by secured, long-term contracts – grows by more than $400 million, to $9.6 billion
• Strong distributable cash flows support ongoing dividend growth
• Special items of $138 million after tax charges, with EPS effect of $0.20
• 2Q 2015 dividend of $0.37 per share compared with $0.335 per share in 2Q 2014

Spectra Energy Corp SE today reported second quarter 2015 financial results. For the quarter, ongoing earnings before interest, taxes, depreciation and amortization (EBITDA) were $652 million, compared with $627 million in the prior-year quarter.

Ongoing distributable cash flow (DCF) for the quarter was $285 million, compared with $277 million in the same quarter last year.

Ongoing net income from controlling interests was $156 million, or $0.23 diluted earnings per share (EPS), compared with $146 million, or $0.22 diluted EPS in second quarter 2014. Reported net income from controlling interests was $18 million, or $0.03 diluted EPS, compared with $146 million, or $0.22 diluted EPS in second quarter 2014.

Effects of Second Quarter 2015 Special Items

CEO COMMENT

"Our second quarter results once again underline our resilient business model, which is anchored by our robust portfolio of fee-based assets and growth projects," said Greg Ebel, chief executive officer, Spectra Energy. "Our ongoing earnings not only exceeded our results for the same quarter last year, they exceeded our own expectations. Even in a challenging energy market, Spectra Energy's business mix continues to demonstrate its ability to generate solid earnings and cash flows, allowing us to drive value for our investors through the ongoing growth in our dividend. Our strong performance in the first and second quarters of the year confirms our confidence in achieving our full year distribution coverage target of at least 1.2.

"During the quarter, we placed $600 million of projects into service, while growing our backlog of projects in execution by $400 million, to a total of $9.6 billion – projects which are all underpinned by secured, long-term contracts. This year, we will bring more than $2 billion of projects into service, creating additional earnings and cash flow growth in 2016 and beyond," continued Ebel. "We continued to demonstrate our solid execution record by placing the Uniontown to Gas City project into service on August 1, well ahead of plan."

SEGMENT RESULTS

Spectra Energy Partners

Spectra Energy Partners reported second quarter 2015 EBITDA of $478 million, compared with $374 million in second quarter 2014. These quarterly EBITDA results reflect increased earnings mainly from expansion projects placed into service: TEAM 2014, TEAM South, and Kingsport. In addition, the increased earnings reflect higher transportation revenues due to higher volumes and tariff rates on the Express pipeline, as well as higher earnings from increased volumes on the Sand Hills natural gas liquids (NGL) pipeline.

Distribution

The Distribution business reported second quarter 2015 EBITDA of $98 million, compared with $112 million in second quarter 2014. This change was almost entirely due to a lower Canadian dollar in second quarter 2015.

Western Canada Transmission & Processing

Western Canada Transmission & Processing reported second quarter 2015 ongoing EBITDA of $115 million, compared with $111 million in second quarter 2014. The 2015 period excludes a special item of $11 million related to employee and overhead reductions. The segment's 2015 ongoing results reflect higher earnings at Empress, mostly offset by the effect of a lower Canadian dollar. 

Field Services

Spectra Energy reported its 50 percent share of ongoing EBITDA from Field Services of $(27) million in second quarter 2015, compared with $54 million in second quarter 2014. The 2015 period excludes a special item of a $194 million non-cash goodwill impairment and $12 million related to a loss on the sale of an asset. The decrease in EBITDA was mainly attributable to continued lower commodity prices, partially offset by asset growth, improved operating efficiencies and other initiatives.

During the second quarters of 2015 and 2014, respectively, NGL prices averaged $0.48 per gallon versus $0.93 per gallon, NYMEX natural gas averaged $2.64 per million British thermal units (MMBtu) versus $4.67 per MMBtu, and crude oil averaged approximately $58 per barrel versus $103 per barrel.

Other

"Other" reported net expense of $12 million and $24 million in the second quarters of 2015 and 2014, respectively, reflecting lower employee benefits costs. "Other" is primarily comprised of corporate expenses, including benefits and captive insurance.

Interest Expense

Interest expense was $166 million in second quarter 2015, compared with $176 million in second quarter 2014, reflecting a lower Canadian dollar.

Income Taxes

Excluding a $72 million tax benefit from a special item related to a goodwill impairment at DCP Midstream in the current quarter, income tax expense was $65 million in second quarters 2015 and 2014 and the effective tax rate was 24 percent in the second quarter of 2015, compared with 26 percent in the second quarter of 2014.

Foreign Currency

Net income was lower by $6 million due to the lower Canadian dollar.

Liquidity and Capital Expenditures

Total debt outstanding at Spectra Energy as of June 30, 2015, was $14.2 billion. Total Spectra Energy liquidity at the end of the quarter was $3.5 billion, including $2.1 billion of available liquidity at Spectra Energy Partners. 

Spectra Energy has $2.8 billion of capital expansion spending planned in 2015, of which $2.2 billion is at Spectra Energy Partners. Excluding reimbursements from noncontrolling interests, total capital spending for the six months ended June 30, 2015, was slightly more than $1 billion, comprised of approximately $760 million of growth capital expenditures and about $260 million of maintenance capital expenditures.

EXPANSION PROJECT UPDATES  

Spectra Energy is making tremendous progress on its goal of securing $35 billion in new projects by the end of the decade. As of the end of second quarter 2015:

• $8.2 billion – in service and delivering solid cash flows
• $9.6 billion – in execution
• $20+ billion – in development

Spectra Energy Partners

At U.S. Transmission, the Uniontown to Gas City project was placed into service and began delivering gas to the Midwest on August 1, earlier than the planned start date of November 1.

U.S. Transmission remains on track with all the projects it has in execution. The OPEN project will bring incremental Marcellus and Utica supply to southern markets on or before the planned November 2015 in-service date. The AIM project in New England began construction this quarter and is scheduled to be in service in the second half of 2016. The company is also on track with the NEXUS project, which has a scheduled fourth quarter 2017 in-service date. FERC resource reports for NEXUS were completed in June, and the company anticipates filing a formal FERC application later this year. The Lebanon Extension project, which will deliver new natural gas supplies to Midwest markets, moved into execution during the quarter, with secured commercial commitments and an anticipated 2017 in-service date. The Gulf Markets, Loudon, Atlantic Bridge, and Sabal Trail projects are also proceeding well towards their respective in-service dates.

The $3 billion Access Northeast project, under development with Eversource and National Grid, continues to advance. Unlike other projects in the region, which are proposing to serve gas LDC's in New England, Access Northeast is focused on the New England electric power market. Project customers – including Eversource, National Grid, and Central Maine Power – serve more than 80 percent of the 6.5 million electric customers in the region.

This project will expand the Algonquin and Maritimes & Northeast systems, utilizing their existing footprints.

The company expects the project's electric power customers to file agreements with their respective public utility commissions soon and anticipates moving Access Northeast into execution later this year or in early 2016, once state regulatory approvals have been received.

Also under development, two Appalachian expansion projects would further connect Marcellus and Utica supply to demand markets. The Greater Philadelphia Expansion and Marcellus to Market projects both received positive responses to open seasons during the quarter and discussions with potential customers are under way.  

In the Liquids business, the Red Lake project to expand the reach of Sand Hills to access growing Permian Basin production will go fully into service once DCP's Zia II plant – which is in the final stages of starting up – comes on line. On the crude oil system, the $135 million Express Enhancement project is currently in execution with an estimated 2016 in-service date.

Longer term, customer interest remains strong in the larger scale crude projects in development. The company continues to expect a late-in-the-decade time frame to secure commitments to advance these projects.

Distribution

Union Gas is on track with the construction of the 2015 Dawn-Parkway project, which is the first of several expansions advancing along the Dawn-Parkway path. This project is scheduled to go into service during the fourth quarter this year. The 2016 Dawn-Parkway project began construction this quarter and is scheduled to be in service in the second half of 2016. The 2017 Dawn-Parkway project was moved into execution during the quarter. Commercial contracts underpinning this $620 million project have been executed, and the facility's application has been filed with the Ontario Energy Board.

Western Canada Transmission & Processing

Work is advancing on projects highlighting the benefits of the company's expansive and attractive existing footprint in Western Canada. Two of these expansions are expected to be in service in 2017: the Jackfish Lake and RAM projects.

The company moved another Western Canada project, High Pine, into execution in the second quarter 2015 to further expand the BC pipeline. The customer agreement has been executed, and the $325 million project will have a late 2016 in-service date.

Field Services

Field Services placed the Lucerne II processing plant in the DJ basin into service this quarter and is in the final stages of starting up its Zia II processing plant in the Permian Basin.   

Additional Information

Additional information about second quarter 2015 earnings can be obtained via the Spectra Energy website: www.spectraenergy.com.

The analyst call, held jointly with Spectra Energy Partners, is scheduled for today, Wednesday, August 5, 2015, at 8:00 a.m. CT. The webcast will be available via the Investors sections of the Spectra Energy and Spectra Energy Partners websites. The conference call can be accessed by dialing (888) 252-3715 in the U.S. or Canada, or (706) 634-8942 internationally. The conference ID is 80785677 or "SE and SEP Quarterly Earnings Call." Please call five minutes prior to the scheduled start time.

A replay of the call will be available until 5:00 p.m. CT on Tuesday, November 3, 2015, by dialing (800) 585-8367 in the U.S. or Canada, or (404) 537-3406 internationally. The conference ID is 18703265. A replay and transcript also will be available via the Spectra Energy and Spectra Energy Partners websites.

Non-GAAP Financial Measures

We use ongoing net income from controlling interests and ongoing diluted EPS as measures to evaluate operations of the company. These measures are non-GAAP financial measures as they represent net income from controlling interests and diluted EPS, adjusted for special items. Special items represent certain charges and credits which we believe will not be recurring on a regular basis. We believe that the presentation of ongoing net income and ongoing diluted EPS provide useful information to investors, as it allows them to more accurately compare our ongoing performance across periods. The most directly comparable GAAP measures for ongoing net income from controlling interests and ongoing diluted EPS are net income from controlling interests and diluted EPS.

The primary performance measure used by us to evaluate segment performance is segment earnings from continuing operations before interest, income taxes, and depreciation and amortization (EBITDA). We consider segment EBITDA, which is the GAAP measure used to report segment results, to be a good indicator of each segment's operating performance from its continuing operations as it represents the results of our segments' operations before depreciation and amortization without regard to financing methods or capital structures. Our segment EBITDA may not be comparable to similarly titled measures of other companies because other companies may not calculate EBITDA in the same manner.

We also use ongoing EBITDA, ongoing segment EBITDA and ongoing Other EBITDA (net expenses) as measures of performance. These measures of performance are non-GAAP financial measures as they represent reported EBITDA, reported segment EBITDA and reported Other EBITDA, adjusted for special items. We believe that the presentation of ongoing EBITDA, ongoing segment EBITDA and ongoing Other EBITDA provide useful information to investors, as they allow investors to more accurately compare a company's, a segment's or Other's ongoing performance across periods. The most directly comparable GAAP measures for ongoing EBITDA, ongoing segment EBITDA or ongoing Other EBITDA are reported EBITDA, reported segment EBITDA or reported Other EBITDA.

We have also presented Distributable Cash Flow (DCF), which is a non-GAAP financial measure. We believe that the presentation of DCF provides useful information to investors as it represents the cash generation capabilities of the company to support dividend growth. We also use ongoing DCF, which is a non-GAAP financial measure, as it represents DCF adjusted for special items. The most directly comparable GAAP measure for DCF and ongoing DCF are net income.

The non-GAAP financial measures presented in this press release should not be considered in isolation or as an alternative to financial measures presented in accordance with GAAP. These non-GAAP financial measures may not be comparable to similarly titled measures of other companies because other companies may not calculate these measures in the same manner.

Forward-Looking Statements

This release includes "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward-looking statements are based on our beliefs and assumptions. These forward-looking statements are identified by terms and phrases such as: anticipate, believe, intend, estimate, expect, continue, should, could, may, plan, project, predict, will, potential, forecast, and similar expressions. Forward-looking statements involve risks and uncertainties that may cause actual results to be materially different from the results predicted. Factors that could cause actual results to differ materially from those indicated in any forward-looking statement include, but are not limited to: state, federal and foreign legislative and regulatory initiatives that affect cost and investment recovery, have an effect on rate structure, and affect the speed at and degree to which competition enters the natural gas and oil industries; outcomes of litigation and regulatory investigations, proceedings or inquiries; weather and other natural phenomena, including the economic, operational and other effects of hurricanes and storms; the timing and extent of changes in commodity prices, interest rates and foreign currency exchange rates; general economic conditions, including the risk of a prolonged economic slowdown or decline, or the risk of delay in a recovery, which can affect the long-term demand for natural gas and oil and related services; potential effects arising from terrorist attacks and any consequential or other hostilities; changes in environmental, safety and other laws and regulations; the development of alternative energy resources; results and costs of financing efforts, including the ability to obtain financing on favorable terms, which can be affected by various factors, including credit ratings and general market and economic conditions; increases in the cost of goods and services required to complete capital projects; declines in the market prices of equity and debt securities and resulting funding requirements for defined benefit pension plans; growth in opportunities, including the timing and success of efforts to develop U.S. and Canadian pipeline, storage, gathering, processing and other related infrastructure projects and the effects of competition, and timing and success of efforts to secure contracts; the performance of natural gas and oil transmission and storage, distribution, and gathering and processing facilities; the extent of success in connecting natural gas and oil supplies to gathering, processing and transmission systems and in connecting to expanding gas and oil markets; the effects of accounting pronouncements issued periodically by accounting standard-setting bodies; conditions of the capital markets during the periods covered by forward-looking statements; and the ability to successfully complete merger, acquisition or divestiture plans; regulatory or other limitations imposed as a result of a merger, acquisition or divestiture; and the success of the business following a merger, acquisition or divestiture. These factors, as well as additional factors that could affect our forward-looking statements, are described under the headings "Risk Factors" and "Cautionary Statement Regarding Forward-Looking Information" in our 2014 Form 10-K, filed on February 27, 2015, and in our other filings made with the Securities and Exchange Commission (SEC), which are available via the SEC's website at www.sec.gov. In light of these risks, uncertainties and assumptions, the events described in the forward-looking statements might not occur or might occur to a different extent or at a different time than we have described. All forward-looking statements in this release are made as of the date hereof and we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

Spectra Energy Corp SE, a FORTUNE 500 company, is one of North America's leading pipeline and midstream companies. Based in Houston, Texas, the company's operations in the United States and Canada include more than 22,000 miles of natural gas, natural gas liquids, and crude oil pipelines; approximately 300 billion cubic feet (Bcf) of natural gas storage; 4.8 million barrels of crude oil storage; as well as natural gas gathering, processing, and local distribution operations. Spectra Energy is the general partner of Spectra Energy Partners SEP, one of the largest pipeline master limited partnerships in the United States and owner of the natural gas, natural gas liquids, and crude oil assets in Spectra Energy's U.S. portfolio. Spectra Energy also has a 50 percent ownership in DCP Midstream, the largest producer of natural gas liquids and the largest natural gas processor in the United States. Spectra Energy has served North American customers and communities for more than a century. The company's longstanding values are recognized through its inclusion in the Dow Jones Sustainability World and North America Indexes and the CDP S&P 500 Climate Disclosure and Performance Leadership Indexes. For more information, visit www.spectraenergy.com and www.spectraenergypartners.com.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

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SOURCE Spectra Energy Corp