cibc fixed income conference - keyera · financial measure” and “forward-looking statements”...
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CIBC Fixed Income Conference
A p r i l 1 0 , 2 0 1 9
Disclaimer
2
In the interests of providing Keyera Corp. (“Keyera” or the “Company”) shareholders and potential investors with information regarding Keyera,
including Management’s assessment of future plans and operations relating to the Company, this document contains certain statements and
information that are forward-looking statements or information within the meaning of applicable securities legislation, and which are collectively
referred to herein as “forward-looking statements". Forward-looking statements in this document include, but are not limited to statements and
tables with respect to: capital projects and expenditures; strategic initiatives; anticipated producer activity and industry trends; and anticipated
performance. Readers are cautioned not to place undue reliance on forward-looking statements, as there can be no assurance that the plans,
intentions or expectations upon which they are based will occur. By their nature, forward looking statements involve numerous assumptions, as
well as known and unknown risks and uncertainties, both general and specific, that contribute to the possibility that the predictions, forecasts,
projections and other forward-looking statements will not occur and which may cause Keyera’s actual performance and financial results in
future periods to differ materially from any estimates or projections of future performance or results expressed or implied by the forward-looking
statements. These assumptions, risks and uncertainties include, among other things: Keyera’s ability to successfully implement strategic
initiatives and whether such initiatives yield the expected benefits; future operating results; fluctuations in the supply and demand for natural
gas, NGLs, crude oil and iso-octane; assumptions regarding commodity prices; activities of producers, competitors and others; the weather;
assumptions around construction schedules and costs, including the availability and cost of materials and service providers; fluctuations in
currency and interest rates; credit risks; marketing margins; potential disruption or unexpected technical difficulties in developing new facilities
or projects; unexpected cost increases or technical difficulties in constructing or modifying processing facilities; Keyera’s ability to generate
sufficient cash flow from operations to meet its current and future obligations; its ability to access external sources of debt and equity capital;
changes in laws or regulations or the interpretations of such laws or regulations; political and economic conditions; and other risks and
uncertainties described from time to time in the reports and filings made with securities regulatory authorities by Keyera. Readers are
cautioned that the foregoing list of important factors is not exhaustive. The forward-looking statements contained in this document are made as
of the date of this document or the dates specifically referenced herein. For additional information please refer to Keyera’s public filings
available on SEDAR at www.sedar.com. All forward-looking statements contained in this document are expressly qualified by this cautionary
statement.
Keyera Representatives
3
Steven Kroeker
• Senior Vice President & Chief Financial Officer
Eileen Marikar
• Vice President, Finance
Avery Reiter
• Director, Treasury
KFS Frac and Storage
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Keyera at a Glance1
4 One of Canada’s largest midstream companies
1. All information as at December 31, 2018, unless otherwise stated.
2. As at March 31, 2019.
3. DBRS and S&P.
Key Metrics
Market Capitalization2 ~$6.6 billion
Enterprise Value2 ~$8.8 billion
2018 Adjusted EBITDA $807 million
2018 Payout Ratio 56%
Dividend $1.80/share p.a. ($0.15/share per month)
Dividend Yield2 ~5.71%
Corporate Credit Ratings3 BBB/Stable
Net Debt/EBITDA 2.6x
2019 Growth Capital Program $800-$900 million
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2018 Record Year even in a Challenging Environment
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Record volumes • Simonette Gas Plant
• Ft Saskatchewan Fractionator
• Condensate system
• Marketing services
Invested ~$1.3B in 2018
Record Financial Performance Operational Milestones
1. Adjusted EBITDA is defined as earnings before interest, taxes, depreciation, amortization, accretion, impairment expenses, unrealized gains/losses and any other non-cash items such as
gains/losses on the disposal of property, plant and equipment.
2. See section of the MD&A in Keyera’s 2018 Year End Report titled “EBITDA” for a reconciliation of Adjusted EBITDA and “Divdends: Distributable Cash Flow” for a reconciliation of distributable cash
flow respectively, for their most closely related GAAP measures.
$617
$807
2017 2018
Adjusted EBITDA1,2
($ Millions)
$2.70
$3.08
2017 2018
Distributable Cash Flow2
($ per share)
$290
$394
2017 2018
Net Earnings ($ Millions)
Integrated Value Chain
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1. Percentage of total realized margin for the year ended December 31st 2018 (2017 - 80%). Realized margin is defined as operating margin excluding unrealized gains and losses from risk management
contracts from the Marketing segment. Realized margin is not a standard measure under GAAP.
Realized Margin by Segment
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* All figures represent last twelve month results as of December 31.
1. Includes intersegment transactions.
2. “Other” includes production segment.
• Keyera’s Gathering and Processing and
Liquids Infrastructure businesses are
predominately fee-for-service
• Marketing segment had an excellent
2018, resulting in a lower fee-for-
service proportion of realized margin
• Keyera’s Marketing business is backed
by ownership in assets
Realized Margin ($ millions)
2016 2017 2018
Fee-for-Service Segments1 $536 $556 $598
Marketing $137 $128 $296
Other2 $11 $14 $13
Total $684 $698 $907
Segment Realized Margin as a % of Total Realized Margin
2016 2017 2018
Fee-for-Service Segments1 78% 80% 66%
Marketing 20% 18% 33%
Other2 2% 2% 1%
Total 100% 100% 100%
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Solid Contractual Foundation
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• Keyera’s current cash flows are well supported by fee-for-service contracts, including take-or-pay
contracts
• Adjusted EBITDA from Keyera’s current ~$2.1 billion capital program will be supported by a
combination of fee-for-service, take-or-pay and area dedication agreements
66%
33%
1%
2018 Realized Margin
Fee-for-Service
Marketing
Other
43%
57%
Take-or-Pay Revenue as a % of 2018 Adjusted EBITDA
Take-or-Pay
Non Take-or-Pay
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Low Counterparty Credit Risk
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Consolidated1,2,3
• Keyera provides essential
infrastructure and marketing services
to industry
• ~82% of Keyera’s total revenue in
2018 came from investment
grade/secured or split rated
counterparties
• Credit risk management strategies
include: letters of credit, netting
agreements, pre-payments
• Broad domestic and international
customer base
1. Based on 2018 revenues.
2. Counterparty ratings are representative of the counterparties’ rating as of March 15th, 2019. Where parental guarantees are in place, the credit rating of the parent is used. The secured category
includes counterparties who are on prepay terms or have posted a letter of credit.
3. Split denotes counterparties with an investment grade rating by one rating agency and non-investment grade rating by another agency.
Gathering and Processing
Liquids Infrastructure Marketing
69%
13%
18% InvestmentGrade/Secured
Split
Non-IG
30%
11%59%
InvestmentGrade/Secured
Split
Non-IG
93%
1%
7%InvestmentGrade/Secured
Split
Non-IG72%
14%
14% InvestmentGrade/Secured
Split
Non-IG
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$-
$200
$400
$600
$800
$1,000
$1,200
$1,400
12/31/13 12/31/14 12/31/15 12/31/16 12/31/17 12/31/18 12/31/19e
Millions ANNUAL CAPITAL EXPENDITURES
Growth Capital Upper End of Growth Capital Range Acquisitions Maintenance Capital
1. Acquisition capital in 2017 reflects the $55 million purchase price for undeveloped land in the Industrial Heartland of Alberta completed in 1Q17, among other actual YTD costs.
2. Keyera’s 50% acquisition of the South Grand Rapids pipeline is included in 2018 Acquisitions.
Investment Opportunities Continue
$800 – $900 Million of Growth Capital Investment in 2019 10
1 2
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Approved Projects Capital Cost (Net, in $ Millions)1
2018 2019 2020
Wapiti Area Gathering & Processing Complex (Phase I) 575
Wapiti Gas Plant (Phase II) & North Wapiti Pipeline System 325
Wapiti Water Disposal System 100
Simonette Inlet & Acid Gas Injection Enhancements 100
Simonette Plant Expansion 85
Pipestone Plant (Phase I) 2 600
Wildhorse Terminal US185
Storage Cavern Development Program at Keyera Fort Saskatchewan 110
TOTAL ~$2.1 Billion
Growth Projects Currently Under Development
11 $2.1B Program expected to achieve 10-15% return on capital3
1. Keyera’s share of estimated capital cost. See Keyera’s 2018 Year End MD&A for capital investment risks and assumptions. 2. Pipestone plant expected to start up in 2021. 3. Return on Capital is defined
as operating margin divided by the estimated capital cost of the projects noted on this slide. Keyera expects to achieve this return, in 2022 once all projects achieve their annual run rate. See “non-GAAP
Financial Measure” and “Forward-Looking Statements” in Keyera’s 2018 Year End MD&A for further details.
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Gathering and Processing Business Unit
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Wapiti
Plant
Growing Presence in Liquids-Rich Area of NW Alberta
Supporting Producer Growth Plans in Liquids-Rich Developments 13
Gross Sour Gas Processing Capacity (Year End) Condensate Handling Capacity (Year End)
300 300
450 450 450
150
300 300
200
0
100
200
300
400
500
600
700
800
900
1000
2017 2018 2019 2020 2021
mm
cf/
d
Simonette Wapiti Pipestone
10,000
27,000 27,000 27,000 27,000
25,000 25,000 25,000
14,000
14,000 14,000
38,000
-
10,000
20,000
30,000
40,000
50,000
60,000
70,000
80,000
90,000
100,000
2017 2018 2019 2020 2021
bb
ls/d
Simonette Wapiti Pipestone
950
mmcf/d 90,000
b/d
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HISTORICAL THROUGHPUT & THE PERCENTAGE CHANGE IN AECO & WTI TO December 31 , 2018
Relatively Stable Throughput
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Liquids Business Unit
Unmatched Infrastructure for NGL and Oil Sands Customers 15
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Keyera Fort Saskatchewan
Gilby Gas Plant
3,650 bbls/d gross (2,930 bbls/d net) of C3+ fractionation capacity
Nevis Gas Plant
3,740 bbls/d of C3+ fractionation capacity
Rimbey Gas Plant
28,000 bbls/d gross (27,640 bbls/d net) of C3+ fractionation capacity
20,000 bbls/d gross (19,740 bbls/d net) of de-ethanization capacity
65,200 bbls/d gross (50,000 bbls/d net) of C3+ fractionation capacity
30,000 bbls/d gross (23,010 bbls/d net) of de-ethanization capacity
Dow Fort Saskatchewan
30,000 bbls/d gross (5,420 bbls/d net) of C3+ fractionation capacity
69,200 bbls/d gross (6,920 bbls/d net) of de-ethanization capacity
Fractionation at Multiple Locations
Adding Value by Processing NGLs from the Gas Stream 16
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Oil Sands Production Continues to Grow
17 Bitumen Production Growth Driving Condensate Demand
Diluent Demand > Condensate Supply
0
500
1,000
1,500
2,000
2,500
3,000
2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
MB
bl/d
Actual CIBC World Markets Forecast
0
100
200
300
400
500
600
700
800
900
1,000
2018A 2019E 2020E 2021E 2022E 2023E 2024E 2025E
MB
bl/
d
WCSB Supply Forecast Demand
Bitumen Production Growing
Source: Estimates as per CIBC World Markets.
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Extensive, Flexible Condensate Infrastructure
• Most connected condensate hub in Western Canada
• Major oil sands delivery options:
• Supply through multiple receipt points:
• Local fractionators and refineries
• Kinder Morgan Cochin pipeline
• Enbridge Southern Lights pipeline and CRW pool
• Western Canada feeder pipelines
• Canadian Diluent Hub
• Rail imports at the Alberta Diluent Terminal
• Storage at Keyera Fort Saskatchewan
• Long-term take-or-pay and fee-for-service agreements:
Industry-Leading Diluent Handling Services 18
– Polaris
– Norlite
– Access
– FSPL
– Grand Rapids
– South Cheecham
– Imperial Oil (Kearl)
– Husky/BP (Sunrise)
– Suncor/Teck/Total (Fort Hills)
– North West Upgrading
– Cenovus (Christina Lake)
– CNRL (Kirby, Primrose)
– JACOS/Nexen (Hangingstone)
– Devon (Jackfish)
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Crude Oil Storage
Expanding and Diversifying Keyera’s Service Offering 19
Wildhorse
Terminal
Baseline
Tank
Terminal
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Marketing Services
Diversified Portfolio of Logistics Services 20
C3
Propane
• Supply exceeds demand in North America
• Majority sold into U.S. markets
• Demand and pricing vary seasonally
• Keyera uses its storage and logistics to
access markets
C2 Ethane
• Sold under long-term agreements to
petrochemical producers in Alberta
• Limited spot market in western Canada
• Produced at three Keyera facilities
C4
Butane
• Sourced and consumed in Alberta
• Feedstock for iso-octane production at
Alberta EnviroFuels
• Seasonal imports from the U.S.
iC8
Iso-octane
• Majority of sales in the U.S.
• High quality gasoline additive
• Produced from butane at Keyera’s
Alberta EnviroFuels facility
C5+ Condensate
• Keyera’s C5+ hub creates industry liquidity
• Consumed in Alberta as diluent for bitumen
• Significant imports required today to meet
demand
• Facilities based marketing
• Prudent risk-management hedging strategy
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Alberta EnviroFuels (AEF)
• Iso-octane (iC8) is a high octane, low vapour pressure gasoline additive
• Butane is the NGL feedstock
• Only merchant iC8 facility in North America
• Licensed capacity of 13,600 bbls/d
• Supply networks and distribution infrastructure used to source feedstock while rail logistics broaden sales markets
• Financial forward markets enable hedging of feedstock costs and large portion of iC8 margin
• iC8 demand driven by premium gasoline demand
• Seasonality is complementary to propane and butane
21 iC8 is a Premium Value-Added Product Produced in Alberta
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1. Calculated as of December 31, 2018 in accordance with Keyera’s debt covenants. For further information regarding covenant calculations, please see
Keyera’s 2018 Year End Report MD&A or copies of the note purchase agreements, all of which are filed on SEDAR.
2. All US dollar denominated debt is translated into Canadian dollars at its swap rate. 2019 maturities as of February 1, 2019.
LONG-TERM DEBT MATURIT IES 2 (exc ludes d rawings under revo l ve r )
2.6x
Net Debt1 to EBITDA
Conservative Capital Structure
22 Well Positioned to Fund Keyera’s $2.1 Billion Capital Program
Issuer Credit Ratings:
• DBRS Limited: BBB with a Stable trend
• S&P Global: BBB/Stable