Enbridge Energy Partners, L.P. First Quarter 2015 Earnings - - PowerPoint PPT Presentation

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Enbridge Energy Partners, L.P. First Quarter 2015 Earnings - - PowerPoint PPT Presentation

Enbridge Energy Partners, L.P. First Quarter 2015 Earnings Presentation May 1, 2015 enbridgepartners.com Legal Notice This news release includes forward-looking statements and projections, which are statements that do not relate strictly to


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enbridgepartners.com

Enbridge Energy Partners, L.P.

First Quarter 2015 Earnings Presentation

May 1, 2015

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Legal Notice

This news release includes forward-looking statements and projections, which are statements that do not relate strictly to historical or current

  • facts. These statements frequently use the following words, variations thereon or comparable terminology: “anticipate,” “believe,” “continue,”

“could,” “estimate,” “expect,” “forecast,” “intend,” “may,” “plan,” “position,” “projection,” “should,” “strategy,” “target,” “will” and similar words. Although the Partnership believes 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 the Partnership’s 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) the Partnership’s 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 the Partnership’s facilities or refineries, petrochemical plants, utilities or other businesses for which the Partnership transports products or to whom the Partnership sells products; (5) hazards and operating risks that may not be covered fully by insurance, including those related to Line 6B and any additional fines and penalties assessed in connection with the crude oil release on that line; (6) changes in or challenges to the Partnership’s tariff rates; (7) changes in laws or regulations to which the Partnership is subject, including compliance with environmental and

  • perational safety regulations that may increase costs of system integrity testing and maintenance; and (8) permitting at federal, state and local

levels in regards to the construction of new assets. “Enbridge” refers collectively to Enbridge Inc. and its subsidiaries other than the Partnership and its subsidiaries. Forward-looking statements regarding “drop-down” growth opportunities from Enbridge are further qualified by the fact that Enbridge is under no obligation to offer to sell us interests in its U.S. projects, and we are under no obligation to buy any such interests. Similarly, any forward- looking statements regarding potential “drop-down” transactions of interests in Midcoast Operating to Midcoast Energy Partners are further qualified by the fact that we are under no obligation to sell to Midcoast Energy Partners, L.P. any such interests, and Midcoast Energy Partners, L.P. is under no obligation to buy any such interests. As a result, we do not know when or if any such transactions will occur. Except to the extent required by law, we assume no obligation to publicly update or revise any forward looking statements, whether as a result

  • f new information, future events or otherwise. Reference should also be made to the Partnership’s filings with the U.S. Securities and

Exchange Commission (the “SEC”), including its Annual Report on Form 10-K for the year ended December 31, 2014 and any subsequently filed Quarterly Report on Form 10-Q for additional factors that may affect results. These filings are available to the public over the Internet at the SEC’s web site (www.sec.gov) and at the Partnership’s web site.

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Agenda

  • 1. Project Execution
  • 2. Crude Oil Supply Fundamentals
  • 3. Drop-Down Outlook
  • 4. 1Q Financial Results
  • 5. Question & Answer
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Market Access Growth Projects

2015 growth projects on-track 2015 Project In-service Capital ($MM)1 Timing Line 67 Alberta Clipper +230 kbpd $240

3Q 2015

Line 61 Southern Access + 240 kbpd Storage & Tankage $395 $360

2Q 2015 3Q15- 2Q2016

Line 78 + 570 kbpd $495

3Q 2015

Organic growth projects deliver low-risk, highly certain cash flow growth

Organic Growth Projects:

 Commercially secured  Low-risk framework  Long-term contracts

1 Represents 100% of forecasted capital cost. Eastern Access and US Mainline Expansion projects are jointly funded 75% by Enbridge and 25% by EEP.

1 2 1 2 3 3

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Project Execution - Sandpiper

  • North Dakota approval

received June 2014

  • ALJ recommends Certificate of

Need permit for approval by Minnesota Public Utility Commission (MPUC)

  • MPUC decision expected in

June

  • Review of proposed pipeline

route to follow

  • Target in service 2017

Stakeholder support for Sandpiper Pipeline Project in Minnesota

Total Secured Capital =

$2.6 B

Positive step in regulatory process

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WCSB and Bakken Crude Oil Supply Outlook

  • Producers have a long-term

investment horizon

  • Strong demand for pipeline

takeaway from the region

  • Tight sand and shale oil

production comparatively more sensitive to short-term price changes

  • Pipeline access to market

enhances producer netbacks

Western Canadian Crude Oil Supply Outlook

Bakken Crude Oil Supply Outlook

1,000 2,000 3,000 4,000 5,000 6,000 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025

kbpd

Forecast Actual

Sources: CAPP Crude Oil Forecast, Markets and Pipelines (June 2014) with January 2015 updates

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Strong Commercial & Fundamental Underpinnings

Low-risk business model largely mitigates

volume sensitivity

Demand for crude oil and pipeline capacity

from Western Canada and Bakken remains strong

Customer demand & connectivity Enbridge/Partnership’s system is currently

  • versubscribed

Pipelines provide the most economical

transportation to market

Still plenty of supply moving by rail from WSCB and Bakken

Liquids pipeline system volume outlook remains strong despite low crude oil prices

2015e EBITDA

EBITDA attributable to EEP (after deducting NCI) Cost of Service/Take-or-Pay Fee-based Commodity Sensitive

Defensive nature of cash flows position EEP to navigate through commodity price uncertainty

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Low-Cost Expansion & Extension Opportunities

New Build HP Upgrades

Low-cost phased expansions are attractive in a low crude price environment

NTD: Map to be updated

1 2 3 4 1 2 1 2 2 3

Market Access Opportunities kbpd 1 Eastern Gulf Coast Access 350+ 2 Flanagan South / Seaway Expansions 200 3 Line 9 Expansion 70 Ex-Superior Expansion Opportunities kbpd 1 Line 61 Twin 550+ 2 SAX Expansion 150 Upstream of Superior Expansion Opportunities kbpd 1 Sandpiper Expansion/ Bakken Interconnect Idle 170 2 Line 2A/LSR Expansion 100 3 Line 2B/4 Capacity Recovery 120 4 Line 3 at 760 370

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Distributable Cash

Pipeline System Upsize Option Capital Cost/ Book Value*

  • Eastern Access

$0.4 (2016/2017) ~ $1.5

  • Mainline Expansion

$0.4 (2016/2017) ~ $1.4

  • Line 3 Replacement**

$0.4 (2018) ~ $0.9

  • Southern Access

Extension

  • ~ $0.6
  • Flanagan South
  • ~ $2.8
  • Seaway/Seaway Twin
  • ~ $2.4

Substantial drop-down opportunities from parent supports long-term growth outlook

* Estimated capital cost or net book value of assets held by Enbridge . ** Line 3 Replacement Joint Funding Agreement under consideration by a Special Committee of the independent Board of Directors., including an option to upsize EEP ownership by 15% one year after the in-service date. Capital cost assumes 50% estimated funding by Enbridge .

~ $10B +

Examples:

Enbridge Liquids Pipelines Drop-Down

Enbridge reviewing potential larger scale drop-down plan to EEP (1)

        

(1) On December 3, 2014, Enbridge announced it is reviewing a potential restructuring plan that would involve the transfer of U.S. liquids pipeline assets to Enbridge Energy Partners, L.P., a U.S. affiliate of Enbridge. This review is underway and has not progressed to a conclusion.

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Q1 2015 Financial Summary

Projects delivering meaningful earnings and cash flow growth

1Adjusted EBITDA includes non-controlling interest. 2Adjusted net income after non-controlling interest and deferred distribution

attributable to preferred unitholders.

3 Distributable cash flow and Coverage metric excludes deferred distribution

attributable to preferred unitholders.

4 Cash coverage excludes Paid-in-Kind distribution.

Financial Results First Quarter 2015 Highlights

Project Execution + Strong Operational Performance = Solid Financial Performance

Earnings

(in $millions, except per unit amounts)

1Q15 1Q14 % Change Adjusted EBITDA1 $432.2 $338.7 ~28% Distributable Cash Flow3 $253.7 $190.3 ~33% Adjusted Net Income2 $142.8 $102.9 ~39% Adjusted Net Income per unit2 $0.26 $0.20

As-declared Coverage Ratio*

1.02x 0.89x 1.07x

0.50x 0.70x 0.90x 1.10x 1.30x

Q1 2015 Q1 2014

Cash coverage 4 Coverage including PIK distribution * Coverage metric excludes deferred distribution attributable to preferred unitholders.

1.21x

 Meaningful cash flow

contributions from growth projects

 Strong liquids pipeline system

deliveries

 Closed $1 billion Alberta Clipper

drop-down acquisition from Enbridge

Distribution coverage* = 1.02x

Unaudited; adjusted results exclude the effect of 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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Forecasted Capital Expenditures and Available Liquidity

2015 Capital Expenditures ($ millions)

1 Eastern Access and US Mainline Expansion capital expenditures are forecasted net of joint funding, with assumed Enbridge 75% funding; Line 3 joint funding currently being negotiated

with Enbridge. Assumes 50-50 joint funding. Sandpiper capital expenditures are forecasted net of 37.5% joint funding from Marathon Petroleum Corp.

2 Represents EEP’s share of Natural Gas capital expenditures of Midcoast Operating, L.P., (“MOLP”) which will be proportionately funded between EEP and Midcoast Energy Partners,

L.P. (“MEP”). Forecast reflects current base 48.4% funding by EEP and 51.6% by MEP.

Eastern Access1 80 US Mainline Expansions1 220 Sandpiper1 228 Line 3 Replacement1 50 Liquids Integrity 290 Liquids Other Growth Enhancements 140 Natural Gas Growth Projects2 145 Maintenance Capital Expenditures2 97 Total Capital Expenditures $1,250

Maintaining Strong Investment Grade Credit Rating is a Top Priority (BBB+/Baa2)

878 273

500 1,000 1,500 3/31/2015 $ millions

Credit Facilities Cash

$1,151

Available Liquidity

Expanded credit capacity and proceeds from recent equity offering bolster liquidity position

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Key Takeaways

Strong Q1 financial performance

  • Meaningful cash flow contributions from growth projects; strong system deliveries

Project execution

  • 2015 growth projects on-track; positive recommendation for Sandpiper

Transformative growth underway with further organic growth potential

  • Low-cost ‘bolt-on’ expansion and extension opportunities remain plentiful in low crude

price environment

EEP aligned and incentivized to ensure MEP success

  • Longer term drop-down strategy intact

Strategic alignment with Enbridge supports long-term growth outlook(1)

  • Enbridge reviewing potential larger scale drop-down plan to EEP

Safety and operational reliability are cornerstones that underpin

  • ur business and growth outlook

(1) On December 3, 2014, Enbridge announced it is reviewing a potential restructuring plan that would involve the transfer of U.S. liquids pipeline assets to Enbridge Energy Partners, L.P., a U.S. affiliate of Enbridge. This review is underway and has not progressed to a conclusion.

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