September 7, 2017 Perry Schuldhaus, President
Enbridge Income Fund Holdings Inc. September 7, 2017 Perry - - PowerPoint PPT Presentation
Enbridge Income Fund Holdings Inc. September 7, 2017 Perry - - PowerPoint PPT Presentation
Enbridge Income Fund Holdings Inc. September 7, 2017 Perry Schuldhaus, President Legal Notice This presentation includes certain forward looking statements and information (FLI) to provide potential investors and shareholders of Enbridge
Legal Notice
This presentation includes certain forward looking statements and information (“FLI”) to provide potential investors and shareholders of Enbridge Income Fund Holdings Inc. (“ENF” or the “Company”) with information about ENF and its investee, Enbridge Income Fund (the “Fund”) and related entities (together with the Fund, the “Fund Group”), including management's assessment of their future plans and
- perations, which FLI may not be appropriate for other purposes. FLI is typically identified by words such as "anticipate", "expect", "project", "estimate", "forecast", "plan", "intend", "target", "believe", “likely”
and similar words suggesting future outcomes or statements regarding an outlook. All statements other than statements of historical fact may be FLI. In particular, this presentation contains FLI pertaining to, but not limited to, information with respect to the following: 2017 and future year guidance; distribution and dividend payouts and growth rate; payout ratio; available cash flow from operations (ACFFO);funding requirements; financing plans; trading volumes and liquidity; future business prospects and performance, including organic growth; future expansions, growth expectations and development opportunities; project execution, including capital costs, expected construction and in-service dates and regulatory approvals, including with respect to Line 3; system throughput and capacity; industry and market conditions, including future WCSB demand and supply growth and takeaway capacity; and future demand for services. Although we believe that the FLI in this presentation is reasonable based on the information available today and the processes used to prepare it, such statements are not guarantees of future performance and you are cautioned against placing undue reliance on FLI. By its nature, FLI involves a variety of assumptions, which are based upon factors that may be difficult to predict and that may involve known and unknown risks and uncertainties and other factors which may cause actual results, levels of activity and achievements to differ materially from those expressed or implied in our FLI and the FLI relating to the Fund Group, including, but not limited to, the following: expected future EBIT and ACFFO; estimated future dividends; the impact of the dividend policy on the Company’s or the Fund Group’s future cash flows; financial strength and flexibility; debt and equity market conditions, including the ability to access capital markets on favourable terms or at all; cost of debt and equity capital; expected supply, demand and prices for crude oil, natural gas, natural gas liquids and renewable energy; economic and competitive conditions; expected exchange rates; inflation; interest rates; changes in tax laws and tax rates; completion of growth projects; anticipated construction and in-service dates; changes in tariff rates; permitting at federal, state, provincial and local levels and renewals of rights of way; capital project funding; the ability of management to execute key priorities; availability and price of labour and construction materials; operational performance and reliability; customer, shareholder, regulatory and other stakeholder approvals and support; hazards and operating risks that may not be covered fully by insurance; regulatory and legislative decisions and actions and costs of complying therewith; public opinion; and weather. We caution that the foregoing list of factors is not exhaustive. Additional information about these and other assumptions, risks and uncertainties can be found in applicable filings with Canadian regulators. Due to the interdependencies and correlation of these factors, as well as other factors, the impact of any one assumption, risk or uncertainty on FLI cannot be determined with certainty. Except to the extent required by law, neither ENF nor the Fund Group assumes any obligation to publicly update or revise any FLI made in this presentation or otherwise, whether as a result of new information, future events or otherwise. All FLI in this presentation and all subsequent FLI, whether written or oral, attributable to ENF or the Fund Group, or any of their subsidiaries or affiliates, or persons acting on their behalf, are expressly qualified in their entirety by these cautionary statements. Non-GAAP Measures This presentation may make reference to non-GAAP measures, including adjusted earnings before interest and income taxes (adjusted EBIT). Adjusted EBIT represents EBIT adjusted for unusual, non- recurring or non-operating factors. ACFFO consists of adjusted EBIT adjusted for non-cash items, representing cash flow from the Fund Group’s underlying businesses, less deductions for maintenance capital expenditures, interest expense and applicable taxes and further adjusted for unusual, non-recurring or non-operating factors not indicative of the underlying or sustainable cash flows of the
- business. ACFFO is important to unitholders as the Fund Group's objective is to provide a predictable flow of distributions to unitholders. ACFFO represents the Fund Group's cash available to fund
distributions to unitholders, as well as for debt repayments and reserves. Management believes the presentation of adjusted EBIT and ACFFO are useful to investors and unitholders as they provide increased transparency and insight into the performance of the Company and the Fund Group. Management uses adjusted EBIT and ACFFO to set targets, including the distribution payout target, and to assess the performance of the Company and the Fund Group. Adjusted EBIT and ACFFO are not measures that have standardized meanings prescribed by generally accepted accounting principles in the United States of America (U.S. GAAP) and are not U.S. GAAP measures. Therefore, these measures may not be comparable with similar measures presented by other issuers. Reconciliations to the most closely related GAAP measures are included in the MD&A filings and/or Supplementary Financial Information available on ENF’s website or in the slides that accompany this presentation, if applicable as well as on www.sedar.com under the ENF and Fund profiles.
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Enbridge Income Fund Infrastructure Asset Base
Canadian Liquids focused asset base: 80% Fund Group ACFFO
3
Business Mix
Liquids Pipelines
- Exceptional North
American Infrastructure
- Excellent market reach
- Low-risk commercial
agreement
- Competitive and stable
tolls
- Visible organic growth
High quality, strategically positioned Canadian Energy Infrastructure assets
78% of EBIT Gas Pipelines Power 11% of EBIT 9% of EBIT
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Low Risk Business Model
Provides strong and predictable results in all environments
Minimal Market Price Risk Counterparty Credit Profile
Cost of service ~15% Take or pay ~25% CTS ~50% Fee for service* ~10% Other <1%
99%
- f cash flow
underpinned by long-term commercial agreements
*Predominately renewable power generation projects underpinned by long-term fixed price power purchase agreements
96%
- f credit exposure
from investment grade customers
- r security
received
Investment grade/security received 96% Other 4%
CFaR
<1%
* Foreign Exchange, Interest Rate & Commodity price risk as at Dec 31, 2016 **CFaR – Measures the maximum cash flow loss that could result from adverse market price movements over a 12 month period within 97.5% confidence level (1.96 std. deviations) under normal market conditions.
<1%
- f cash flow subject
to market price risks including commodity, interest and foreign exchange
Strong Commercial Constructs
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Strong Counterparty Credit Profile*
Major liquids pipeline systems underpinned by strong, investment grade customers
*As of August 31, 2017
MAINLINE TOP 10 SHIPPERS
Shipper 1: Integrated AA+/Aaa Shipper 2: Integrated A-/A2 Shipper 3: Refiner BBB/Baa2 Shipper 4: Integrated A-/Baa1 Shipper 5: Integrated A/Aa2 Shipper 6: Refiner AA-/Aa3 Shipper 7: Refiner BBB/Baa2 Shipper 8: Producer BBB/Ba2 Shipper 9: Midstream BBB-/Ba1 (security requested) Shipper 10: Refiner BBB+/Baa2 (security provided)
REGIONAL OIL SANDS TOP 10 SHIPPERS
Shipper 1: Integrated A-/Baa1 Shipper 2: Producer BBB/Ba2 Shipper 3: Integrated AA+/Aaa Shipper 4: Integrated BBB+/Baa2 Shipper 5: Producer A-/Baa2 Shipper 6: Producer A+/Aa3 Shipper 7: Producer AA-/Aa2 (security provided) Shipper 8: Producer A+/A1 Shipper 9: Producer NR/Baa1 Shipper 10: Integrated A-/NR
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2016 2017e
2017 Outlook
*Available cash flow from operations (ACFFO) is a non-GAAP measure. For more information on non-GAAP measures please refer to disclosures in the news release.
Secured Growth Projects in Execution
Strong performance from existing assets and $3.7B of capital in service in 2017 drives outlook
PROJECTS
- EST. COST ($B)
2017
JACOS Hangingstone $0.2 Norlite Diluent Pipeline $0.9 Regional Oilsands Optimization Athabasca Pipeline Twin
- Wood Buffalo Extension
$2.6
2019
Line 3 Replacement Program $5.3
Total Projects in Execution $9.0
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Fund Group 2017 ACFFO Guidance
C$ millions
$2,100 $1,900
~ 9%
Mainline – Secured Growth
- Canadian Line 3 Replacement*
– Restores line capacity to 760 kbpd (+375 kbpd) – Expected In-Service: 2019 – Capital: $5.3B** – 15 year toll surcharge on every mainline barrel – Low to medium teens returns on significant incremental investment – Toll mechanism offers volume downside protection – Beginning construction on certain segment in Canada
Improved reliability and capacity expansion
* Enbridge Inc. and Enbridge Energy Partners, L.P. are undertaking the U.S. portion of the Line 3 Replacement. ** Represents Canadian portion of Line 3 project. Total project cost is $8.2B including US portion.
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Line 3 Replacement
Edmonton Hardisty Kerrobert Gretna Superior Regina
Construction beginning Completed segments to date Construction under way
Line 3 – Minnesota Timeline
May 2017 Draft EIS published 3Q17 Final EIS; MNPUC review begins 1Q18 ALJ recommendation 2Q18 Final MNPUC approval 2H18 Construction begins in Minnesota 2H19 In service
Enbridge Income Fund Liquids Pipelines Asset Base
A Key component of North America’s Premier Portfolio
9 Cushing Hardisty Patoka Superior Sarnia Chicago Gulf Coast Markets ENF Southern Lights Other ENB
- High quality producing basins
- Access to the best refining markets
- Competitive tolls drive highest producer netbacks
- Stable, low risk commercial underpinnings
- Strong, creditworthy customers
- Unique service offerings & flexibility
North America’s Premier Portfolio
Mainline Competitive Positioning
- 1. Mainline system is sole source
- f supply for ~1.9 mmbpd
refinery demand
- 2. >1 mmbpd of downstream
pipeline take or pay commitments support Mainline system throughput certainty
- 3. Lowest tolls to the Midwest
(PADD II) and USGC
Mainline utilization driven by connected refineries and downstream pipelines
1.9 mmbpd
Sole sourced supply
>1.0 mmbpd
Downstream take-or-pay commitments
1 2 3
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Mainline Netback Analysis
- Midwest markets provide
premium netback to WCSB producers
- USGC market access ensures
that Canadian heavy is at pipeline toll parity to Maya
Heavy crude – Indicative tolls
Hardisty Netback PADD II $48 USGC $42
$3/Bbl $8/Bbl $5/Bbl
Chicago Pricing Maya $53 USGC Pricing Maya $50
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+500 kbpd
Midwest Markets
Superior
Gulf Coast Markets
Mainline – Potential Future Expansions
Low cost, highly executable, staged expansions to match supply
Incremental Capacity 2019
Capacity
(KBPD)
System DRA Optimization +75 BEP Idle* +100
Incremental Capacity 2019+
System Station Upgrades +100 Line 4 Capacity Restoration +75 Line 13 Reversal +150 Total Unsecured Incremental Capacity +500
*Incremental capacity refers to long-haul volumes
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Mainline – WCSB Capacity Requirements
Mainline expansions are best positioned to meet industry capacity needs
Western Canadian Demand + Existing Infrastructure Enbridge Mainline Line 3 Replacement + 2019 Incremental Capacity
Post-2019 Enbridge incremental capacity
- 500
1,000 1,500 2,000 2,500 3,000 3,500 4,000 4,500 5,000 5,500 6,000 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030
WCSB Capacity Outlook (KPBD)
CAPP 2017
Western Canadian Demand + Existing Infrastructure Enbridge Mainline
Line 3 Replacement + 2019 Incremental Capacity Post 2019 Enbridge Incremental Capacity
Source: CAPP 2017 Forecast, Enbridge Estimates
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$1.40 $1.59 $1.87 $2.05 $- $0.50 $1.00 $1.50 $2.00 $2.50
2014 2015 2016 2017e 2019e
Significant Dividend Income
Visible dividend growth through 2019 and beyond
- Low cost, phased expansions of the
Mainline
- Alliance expansion
– Expression of interest underway
- Right of first offer on growth within
existing Liquids asset footprint
Growth Beyond 2019 Dividend per Share 2014 – 2019e
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Takeaways
- High-quality assets generate strong and predictable
cash flow
- Low risk business model designed to perform
consistently in all market conditions
- $9 billion of growth projects support dividend by
10% annually through 2019
- Strategically positioned assets provides strong
platform to extend growth beyond 2019
SLIDE 15
Q&A
Appendix
Alliance Pipeline
- Connects growing liquids rich supply to
large Midwest market
- Fully contracted to target levels
- Expandable
- Integrated strategy with Enbridge
Canadian Midstream
600 1,200 1,800
2017
New service offering Mmcf/d
Source: ENB Gas & NGL Fundamentals
Only rich gas export pipeline out of WCSB
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BAKKEN DUVERNAY MONTNEY HORN RIVER
Alliance Pipeline
Chicago
IT/Seasonal US Firm Canada
5 10 15 2015 2020 2025
Liquids rich gas supply (Bcf/d)
Bakken Montney Duvernay
Alliance Expansion
- Project: Expression of interest for 500 Mcf/d
- Estimated CapEx: $500M*
- Projected in-service: 2020
- Demand continues to increase for egress
solutions out of Western Canada
Development Opportunities on the Horizon
* Enbridge Income Fund’s share
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Alliance Expansion
Oil Sands
- Unparalleled gathering system that
connects WCSB crude oil with transportation access to valuable markets
- Current throughput capacity into
Edmonton & Hardisty hubs ~2MMbpd
– 9 connected Oil Sands projects, 11 by year end – Average contract length of 25 years
Stable and secure, embedded growth
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Project ISD $C B
Athabasca Pipeline Twin
in service $1.3
Wood Buffalo Extension
end of 2017 $1.3
Norlite Diluent Pipeline
commercially in service *$0.9
JACOS Lateral
Sept 2017 $0.2
Oil Sands
Stable and secure, embedded growth
$3.7B of projects in service in 2017 Potential for future grow th
- Third party volumes on Norlite
- Cheecham Terminal enhancement
* ENF share of total capital cost. Total project cost is expected to be $1.3B with Keyera funding 30% of the project
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Green Power Asset Base
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Asset Overview
Average remaining length of PPAs is ~12 years
Facility Generating Capacity (MW) Our Interest Location
WIND Lac Alfred 308 67.5% QC Massif du Sud 154 80% QC
- St. Robert Bellarmin
82 50% QC Ontario Wind 190 100% ON Talbot 99 100% ON Greenwich 99 100% ON SunBridge 11 50% SK Blackspring Ridge 300 50% AB Magrath 30 33% AB Chin Chute 30 33% AB SOLAR Sarnia 80 100% ON Amherstburg 15 100% ON Tilbury 5 100% ON WASTE HEAT RECOVERY NRGreen 33 50% AB/SK Total 1,437 1,052 MW
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