First Quarter 2013 Earnings Presentation
May 1, 2013
Slides posted at www.enbridgepartners.com/q
First Quarter 2013 Earnings Presentation May 1, 2013 Slides posted - - PowerPoint PPT Presentation
First Quarter 2013 Earnings Presentation May 1, 2013 Slides posted at www.enbridgepartners.com/q Legal Notice This presentation includes certain forward looking information (FLI) to provide Enbridge Energy Partners, L.P. (EEP) and
Slides posted at www.enbridgepartners.com/q
2 This presentation includes certain forward looking information (“FLI”) to provide Enbridge Energy Partners, L.P. (“EEP”) and Enbridge Energy Management, L.L.C. (“EEQ”) investors and potential investors with information about EEP and EEQ and management’s assessment of the future plans and operations, which may not be appropriate for other purposes. FLI involves statements that frequently use words such as “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecast,” “intend,” “may,” “plan,” “position,” “projection,” “should,” “strategy”, “will” and similar words. Although we believe that such forward looking statements are reasonable based on currently available information, such statements involve risks, uncertainties and assumptions and are not guarantees of performance. Future actions, conditions or events and future results of operations may differ materially from those expressed in these forward-looking statements. Many of the factors that will determine these results are beyond Enbridge Partners’ ability to control or predict. Specific factors that could cause actual results to differ from those in the forward-looking statements include: (1) changes in the demand for or the supply of, forecast data for and price trends related to crude oil, liquid petroleum, natural gas and NGLs, including the rate of development of the Alberta Oil Sands; (2) Enbridge Partners’ ability to successfully complete and finance expansion projects; (3) the effects of competition, in particular, by other pipeline systems; (4) shut-downs or cutbacks at facilities of Enbridge Partners or refineries, petrochemical plants, utilities or other businesses for which Enbridge Partners transports products or to whom Enbridge Partners sells products; (5) hazards and operating risks that may not be covered fully by insurance; (6) changes in or challenges to Enbridge Partners’ tariff rates; and (7) changes in laws or regulations to which Enbridge Partners is subject, including compliance with environmental and operational safety regulations that may increase costs of system integrity testing and maintenance. Our FLI is subject to risks and uncertainties pertaining to operating performance, regulatory parameters, project approval and support, weather, economic conditions, interest rates and commodity prices, including but not limited to those discussed more extensively in our filings with U.S. securities regulators. The impact of any one risk, uncertainty or factor on any particular FLI is not determinable with certainty as these are interdependent and our future course of action depends on management’s assessment of all information available at the relevant time. Except to the extent required by law, we assume no obligation to publicly update or revise any FLI, whether as a result of new information, future events or
EEP’s and EEQ’s SEC filings, including its most recently filed Annual Report on Form 10-K and subsequently filed Quarterly Reports on Form 10-Q, for a more detailed discussion of risk factors. This presentation makes reference to certain financial measures, such as adjusted net income, which are not recognized under generally accepted accounting principles, referred to as GAAP.
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U/C
In-service Under construction Being phased-in Regulatory process
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Cushing Houston Chicago/ Flanagan Port Arthur 1 3 2 Enbridge Energy Partners Projects (EEP) ~ $7.3B*
Sandpiper Pipeline Project ($2.5B)
US Mainline Expansions ($2.4B): Line 67 Expansion (border to Superior)
Line 61 Expansion (Superior to Flanagan)
Chicago Connectivity
Eastern Access Expansions ($2.4B): Line 5 Expansion
Line 62 Spearhead North Expansion
Line 6B Replacement
EEP/ENB joint funded
*represents total capital before joint funding
3 1 2 3
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Montreal Superior
Canadian/U.S. East Coast Refinery Markets U.S. Gulf Coast Refinery Markets
Sarnia EEP North Dakota System Patoka Enbridge (ENB) & Enbridge Partners (EEP) Market Access Programs
4 5 4 5 6 5 1 2 4 6 6
U.S. Mid-West Refinery Markets
Enbridge Inc. Projects (ENB)
Seaway Pipeline - ENB and EPD JV
Flanagan South Pipeline
Seaway Pipeline Twin & Lateral
Toledo Pipeline Partial Twin
Line 9 Reversal & Expansion
Southern Access Extension
Trunkline JV
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5 2 3 4 5 6 7 Memphis
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Note: Eastern Access and Mainline Expansion liquids expansion projects are jointly funded by EEP & ENB.
*Note: based on 2013 forecast
Liquids Pipelines 80% Natural Gas 20%
0% 20% 40% 60% 80% 100%
2008 2009 2010 2011 2012 2013 2014 2015 2016
60% 12% 18% 59% 23% 28%
Cost of Service/Take-or-Pay: Contribution from Liquids and Natural Gas business cost of service and take-or-pay contracts. Fee-based: Contribution from Liquids and Natural Gas business fee-based service. Commodity Sensitive: Contribution from Natural Gas business from its commodities length (before hedging). Contribution is based on revenues from Liquids segment and gross margin from Natural Gas segment, including non-controlling interest.
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1Q 109.2 1Q 95.7
50 100
2012 2013
$ millions
Excludes earnings attributable to non-controlling interest
1Q 291.5 1Q 281.0
50 100 150 200 250 300
2012 2013
$ millions
Includes non-controlling interest
1Q $0.28 1Q $0.21
$0.00 $0.10 $0.20 $0.30
2012 2013
Excludes earnings attributable to non-controlling interest
YTD 0.79x YTD 0.79x
0.00x 0.20x 0.40x 0.60x 0.80x 1.00x
2012 2013
Unaudited; adjusted results exclude the impact of: (a) additional environmental costs, net of insurance recoveries, associated with the incident on Line 6B; and (b) non-cash, mark-to- market net gains and losses; among other adjustments. Refer to the Non-GAAP Reconciliation tables presented in the supplemental slides.
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1.86 1.81 1.76 1.74 1.84 0.24 0.24 0.21 0.21 0.22 0.22 0.22 0.21 0.17 0.13
1.00 1.50 2.00 2.50
1Q12 2Q12 3Q12 4Q12 1Q13
Volume by System (mmbpd)
Lakehead Mid-Continent North Dakota
159.0 155.5 153.5 133.0 154.3
50 100 150 200 1Q12 2Q12 3Q12 4Q12 1Q13 $ millions
Unaudited; adjusted results exclude the impact of: (a) additional environmental costs, net of insurance recoveries, associated with the incident on Line 6B; and (b) non-cash, mark-to- market net gains and losses; among other adjustments. Refer to the Non-GAAP Reconciliation tables presented in the supplemental slides.
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52.5 43.3 60.2 42.9 26.4
10 20 30 40 50 60 70 1Q12 2Q12 3Q12 4Q12 1Q13 $ millions
942 1,062 1,065 998 964 1,319 1,291 1,219 1,233 1,252 315 332 343 333 332
200 300 400 500 600 700 800
1,000 1,500 2,000 2,500 3,000 1Q12 2Q12 3Q12 4Q12 1Q13 Average Rig Count EEP Main Regions Volume by System (mmbtu/d in thousands) Anadarko East Texas North Texas Rig Count
Unaudited; adjusted results exclude the impact of: (a) non-cash, mark-to-market net gains and losses; among other adjustments. Refer to the Non-GAAP Reconciliation tables presented in the supplemental slides.
1 Eastern Access and US Mainline Expansion capital expenditures are forecasted net of joint funding, with assumed Enbridge Inc. 60% funding; all amounts in $ millions.
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1,283 1,611 228 242
500 1,000 1,500 2,000 12/31/2012 3/31/2013 $ millions
Credit Facilities Cash
1,852 1,511
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0.00x 0.25x 0.50x 0.75x 1.00x 1.25x 2006 2007 2008 2009 2010 2011 2012 2013(e) 2016(e) Long Range Coverage Target
Guidance range
* Coverage includes EEQ paid-in-kind distribution.
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