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0 FORWARD-LOOKING INFORMATION This Corporate Presentation contains certain forward- looking statements or information (collectively referred to as forward - looking statements) within the meaning of applicable securities legislation. All


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FORWARD-LOOKING INFORMATION

This Corporate Presentation contains certain forward-looking statements or information (collectively referred to as “forward-looking statements”) within the meaning of applicable securities legislation. All statements, other than statements of historical fact included in this Corporate Presentation, which address activities, events or developments that Inter Pipeline expects or anticipates to occur in the future, are forward-looking statements. Forward-looking statements often contain terms such as "may", "will", "should", "anticipate", "expect", “continue”, “estimate”, “believe”, “project”, “forecast”, “plan”, “intend”, “target”, "outlook", "focus", "could" and similar words suggesting future outcomes or statements regarding an outlook. Forward-looking statements in this Corporate Presentation include, but are not limited to, statements regarding: 1) Inter Pipeline’s belief that it is well positioned to maintain its current level of dividends to its shareholders; 2) Inter Pipeline being well positioned to operate and grow in the future including anticipated benefits of acquisitions and growth opportunities associated with acquisitions; 3) financial forecasts or anticipated financial performance; 4) timing and cost of capital projects, and forward EBITDA (as defined herein) estimates in respect of these projects (including PDH and PP facilities); and 5) capital expenditure forecasts. Readers are cautioned not to place undue reliance on forward-looking statements, as such statements are not guarantees of future performance. Inter Pipeline in no manner represents that actual results, levels of activity and achievements will be the same in whole or in part as those set out in the forward-looking statements herein. Such information, although considered reasonable by Inter Pipeline may later prove to be incorrect and actual results may differ materially from those anticipated in the forward-looking statements. Inter Pipeline applies a variety of factors and assumptions when making forward-looking statements and making forecasts, projections, predictions or estimations, which include, but are not limited to, Inter Pipeline’s ability to successfully implement its strategic initiatives and achieve expected benefits; Inter Pipeline’s ability to maintain its investment grade credit ratings; the availability and price of labour, equipment and materials; assumptions concerning operational reliability; the availability and price of energy commodities; the availability of adequate levels of insurance; and general economic and business conditions. By their nature, forward-looking statements are subject to various known and unknown risks, uncertainties and other factors, which are beyond Inter Pipeline’s control, including, but not limited to: the status, credit risk and continued existence of customers having contracts with Inter Pipeline and its affiliates; competitive factors, pricing pressures and supply and demand in the oil and gas transportation, natural gas liquids (NGL) processing and storage industries; fluctuations in currency and interest rates; risks of war, hostilities, civil insurrection, instability and terrorist actions, as well as political and economic conditions, in or affecting countries in which Inter Pipeline and its affiliates operate; public opinion regarding the production, transportation and use of oil and gas; severe weather and environmental conditions; risks associated with technology; Inter Pipeline’s ability to access external sources of debt and equity capital; the potential delays of, and costs of overruns on, construction projects in all of Inter Pipeline’s business segments; Inter Pipeline’s ability to make capital investments and the amounts of capital investments; changes in laws and regulations, including environmental, regulatory and taxation laws, and the interpretation of such changes to Inter Pipeline’s business; the risks associated with existing and potential or threatened future lawsuits and regulatory actions against Inter Pipeline and its affiliates; increases in maintenance, operating or financing costs; difficulty in obtaining necessary regulatory approvals or land access rights and maintenance of support of such approvals and rights; the realization of the anticipated benefits of acquisitions; and such other risks and uncertainties described from time to time in Inter Pipeline’s reports and filings with the Canadian securities authorities. The impact

  • f any one assumption, risk, uncertainty or other factor on a particular forward-looking statement cannot be determined with certainty, as these are interdependent and

Inter Pipeline’s future course of action depends on management’s assessment of all information available at the relevant time. Readers are cautioned that the foregoing list of assumptions, risks, uncertainties and factors is not exhaustive. See also the section entitled RISK FACTORS of Inter Pipeline’s most recent Management’s Discussion and Analysis filed on SEDAR at www.sedar.com for further risk factors. The forward-looking statements contained in this Corporate Presentation are made as of the date of this document and, except to the extent expressly required by applicable securities laws and regulations, Inter Pipeline assumes no obligation to update or revise forward-looking statements made herein or otherwise, whether as a result of new information, future events, or

  • therwise. The forward-looking statements contained in this document and all subsequent forward-looking statements, whether written or oral, attributable to Inter

Pipeline or persons acting on Inter Pipeline’s behalf are expressly qualified in their entirety by these cautionary statements.

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INTER PIPELINE

  • Operates world scale energy

infrastructure assets

  • Stable in an uncertain market

with strong balance sheet and investment grade credit rating

  • Sustainable dividend profile

with upside growth potential

  • Well positioned to capitalize on

future growth opportunities

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WORLD SCALE ENERGY INFRASTRUCTURE ASSETS

2.3 million b/d of contracted capacity Conventional Oil Pipelines Over 240,000 b/d

  • f production

capacity 3,900 km pipeline network in western Canada Oil Sands Transportation NGL Processing Bulk Liquid Storage 27 million barrels

  • f storage capacity

in Europe

49% 26% 17% 8%

2017 March YTD EBITDA

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AREAS OF OPERATION

IRELAND ENGLAND GERMANY SWEDEN DENMARK

Canada Europe 2017 March YTD EBITDA 92% 8%

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LOW RISK BUSINESS STRATEGY

WELL DIVERSIFIED

  • Large-scale and

strategically located assets

  • Capital-efficient growth
  • pportunities

OPERATIONAL EXCELLENCE

  • Exceptional EH&S

performance and reliability

  • Industry leading project

execution

STRONG FINANCIAL POSITION

  • Solid balance sheet
  • Excellent access to

capital markets

  • BBB+ credit rating

STABLE CASH FLOW

  • 75% of EBITDA from

cost of service and fee based contracts

  • Majority investment

grade counterparties

DIVIDEND GROWTH & STABILITY

14 consecutive dividend increases 5–year dividend CAGR ~9%

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DIVIDEND GROWTH

$/Share

9.0%

CAGR

2012-2017F

6.8%

CAGR

2007-2017F 2017F based on actual dividends to May 2017 and $0.135/share per month thereafter

$0.84 $0.84 $0.85 $0.91 $0.97 $1.06 $1.18 $1.32 $1.49 $1.57 $1.62 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017F

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DIVIDEND STABILITY

FFO is attributable to shareholders and before sustaining capital; corporate costs have been allocated based on IPL assumptions

$ Million $0 $300 $600 $900

2011 FFO 2011 Dividend 2012 FFO 2012 Dividend 2013 FFO 2013 Dividend 2014 FFO 2014 Dividend 2015 FFO 2015 Dividend 2016 FFO 2016 Dividend

Oil Sands Transportation Conventional Oil Pipelines Bulk Liquid Storage NGL Processing

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RECENT DEVELOPMENTS

  • Record pipeline throughput of 1,461,300

b/d during Q1 2017

  • 14th consecutive dividend increase to

$1.62 per share annually

  • Acquired the remaining 15% interest in

Cold Lake for $528 million

  • Secured a new long term cost of service

contract for CNR’s Kirby North project

  • Acquired a large scale ethane-plus

extraction, transportation and fractionation business for $1.35 billion

  • Potential propane dehydrogenation

(“PDH”) and polypropylene (“PP”) facility development totaling ~$3.1B

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49% 2017 March YTD EBITDA

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OIL SANDS TRANSPORTATION

  • Three major oil sands

pipeline systems with combined ultimate capacity

  • f 4.6 million b/d
  • Corridor
  • Cold Lake
  • Polaris
  • Over 3,300 km of pipeline and

3.8 million barrels of storage

  • Long term cost of service

agreements

  • Substantial available capacity

for 3rd party growth projects

AOSP IMPERIAL KEARL HUSKY SUNRISE SUNCOR AOC HANGINGSTONE JACOS / NEXEN HANGINGSTONE FCCL NARROWS LAKE FCCL CHRISTINA LAKE CNR KIRBY SOUTH FCCL FOSTER CREEK OSUM ORION IMPERIAL COLD LAKE CNR PRIMROSE / WOLF LAKE BRUDERHEIM FACILITY

LAMONT TERMINAL

CNR KIRBY NORTH

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200 400 600 800 1,000 1,200 1,400 Current Throughput* Installed Capacity Ultimate Capacity

CORRIDOR PIPELINE CAPACITY

*Period ended March 31, 2017; ** subject to existing shipper approval

POTENTIAL 3RD PARTY CAPACITY** CONTRACTED VOLUMES

416 465 1,400 935 465 000’s b/d

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200 400 600 800 1,000 1,200 1,400 1,600 1,800

Original Cold Lake FCCL CNR Kirby North & South Osum Orion Ultimate Capacity AVAILABLE CAPACITY

COLD LAKE PIPELINE CAPACITY

CONTRACTED VOLUMES

000’s b/d 650 500 90 14 1,900 ~645 ~1,255 2,000

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100 200 300 400 500 600 700 800

FCCL Imperial Kearl Husky Sunrise CNR Kirby North & South Suncor Connection JACOS Hangingstone AOC Hangingstone Ultimate Capacity

POLARIS PIPELINE CAPACITY

000’s b/d 350 120 30 24 10 7 5 1,300 ~755 ~545 1,300

AVAILABLE CAPACITY CONTRACTED VOLUMES

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OVER-BUILD STRATEGY

  • Successfully completed expansion of the Cold Lake and Polaris pipeline

systems increasing total available capacity to 2.3 million b/d

  • Over-build economics supported by existing contracts
  • Well positioned to accommodate high return “bolt-on” projects

(000’s b/d) Contracted Available Ultimate Cold Lake 1,255 645 1,900 Corridor 465 935* 1,400 Polaris 545 755 1,300 Total Capacity 2,265 2,335 4,600

*Subject to existing shipper approval

Identified ~$4 billion of long term potential oil sands opportunities

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$0 $100 $200 $300 $400

ATTRACTIVE “BOLT-ON” PROJECT MULTIPLES

  • Over $580 million in announced

bolt-on oil sands connections

  • 11 connections with an average

EBITDA multiple of ~3.2x

  • Identified growth opportunities

largely composed of bolt-on projects

EBITDA Multiple Range

< 2.0x

3 PROJECTS

2.1x – 4.0x

4 PROJECTS

4.1x – 6.0x

4 PROJECTS

Total Capital ($ Million)

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COMPETITIVE ADVANTAGE

Less regulatory risk Less capital risk Less schedule risk Greater flexibility to accommodate small & large scale projects

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26% 2017 March YTD EBITDA

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NGL PROCESSING

*50% working interest in the Empress V facility

Cochrane ~100,000 b/d Capacity Empress II & V* ~105,000 b/d Capacity Redwater Olefinic Fractionator ~40,000 b/d Capacity Boreal Pipeline ~43,000 b/d Capacity Pioneer I & II ~40,000 b/d Capacity

  • Large scale NGL infrastructure
  • Three straddle plants

strategically located on the TransCanada Alberta System

  • Two offgas plants with

dedicated supply agreements

  • Boreal pipeline with low cost

expansion up to 125,000 b/d

  • Ethane-plus fractionation at

Redwater

  • Potential PDH and PP facility

development totaling ~$3.1 billion

  • Successful integration of

Williams Canada acquisition

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WILLIAMS CANADA ACQUISITION SUMMARY

  • Acquired during a low period in the

commodity cycle

  • Price of $1.35 billion represents a 45%

discount to original cost of ~$2.5 billion

  • Contributed $37 million in EBITDA during

Q1 2017 compared to ~$40 million in fiscal 2015

  • Expected to be immediately accretive to

funds from operations per share

  • Diversifies and strengthens existing

large scale NGL processing business

  • Underpinned by long term supply

and ethane-ethylene sales agreements

  • Retained employees provide offgas

and petrochemical expertise

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20 Redwater Olefinic Fractionator Offgas AECO Offgas AECO Offgas Plants Boreal Pipeline System

Marketed Products

1

Ethane- Ethylene Mix

1

  • Extraction of ethane-plus from offgas received directly from Suncor and CNRL Horizon

upgraders

  • The ethane-plus mix is transported to the Redwater Olefinic Fractionator via the Boreal

pipeline system where it is fractionated Proposed PDH Facility Market Propane

PDH Polymer Grade Propylene

2

  • Propane sourced from Redwater Olefinic Fractionator and the local market would be

processed at PDH facility into polymer grade propylene

  • Polymer grade propylene to be used as feedstock at the PP facility and processed into

polypropylene

OFFGAS PROCESSING, PDH & PP OVERVIEW

Proposed PP Facility

2

Redwater Propane Polypropylene

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21 Redwater Olefinic Fractionator sales volume

000’s b/d

OFFGAS VOLUMES AND COMPOSITION

Redwater Olefinic Fractionator Product Composition* Ethane-Ethylene 39% Propane 28% Normal Butane 8% Polymer Grade Propylene 12% Alky Feed 9% Olefinic Condensate 4%

  • Pioneer II offgas extraction facility in

service since February 2016, adding 15,000 b/d of production capacity

  • Volumes for 2016 were negatively

impacted by:

  • Wildfires in the Fort McMurray region
  • Planned Suncor upgrader turnaround

*For the period ended March 31, 2017; composition based on production volumes which may differ from sales volumes

Ethane-Ethylene Contract In Service 5 10 15 20 25 30 35 2012 2013 2014 2015 2016 Q1 2017

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PDH AND PP OPPORTUNITY

  • Proposed petrochemical complex

that will convert propane into polypropylene

  • Design capacity to consume ~22,000 b/d
  • f propane to produce ~525,000 tonnes

per year of polypropylene

  • Polypropylene is a high value, easy to

transport plastic used in the manufacturing

  • f a wide range of finished products
  • Awarded $200 million of royalty credits

under the Alberta Government’s Petrochemical Diversification Program

  • As at March 31, 2017, ~$250 million

invested on the PDH and PP facilities

  • Targeting FID around mid-2017
  • In service date expected mid-2021
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17% 2017 March YTD EBITDA

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CONVENTIONAL OIL PIPELINES

  • 3,900 km of oil pipelines

servicing over 100 producers

  • 100% fee based business,

excluding midstream marketing

  • Strong production from

Viking formation

  • 10-year take or pay

agreement on the Bow River pipeline system

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CONVENTIONAL EBITDA

$ Million

9.9%

CAGR

2011-2016

$0 $50 $100 $150 $200 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016

Oil Gathering Hardisty Midstream Marketing

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50 100 150 200 250 2011 2012 2013 2014 2015 2016 Q1 2017

Mid-Saskatchewan Bow River Central Alberta

CONVENTIONAL THROUGHPUT

000’s b/d 212 205 187 176 170 201 210

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8% 2017 March YTD EBITDA

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BULK LIQUID STORAGE

  • 16 petroleum and

petrochemical storage terminals

  • Approximately 27 million

barrels of storage capacity

  • Fee based revenue structure
  • Average utilization rate
  • f 99%*

*Period ended March 31, 2017

Shannon Immingham West Tyne Riverside Immingham East Mannheim North Mannheim South Ensted Asnaes Gulfhavn Malmo Gavle Sodertalje Gothenburg Stigsnaes

IRELAND ENGLAND GERMANY SWEDEN DENMARK

Seal Sands

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STRATEGIC DRIVERS

  • Long-life infrastructure assets
  • Strong organic and acquisition

based investment potential

  • Geographic diversification, mature

markets

  • 100% fee based cash flow
  • Strong financial results despite low

commodity price environment

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CAPACITY UTILIZATION

Storage (Million barrels) Utilization (%) 0% 20% 40% 60% 80% 100% 6 12 18 24 30 Q1 2012 Q1 2013 Q1 2014 Q1 2015 Q1 2016 Q1 2017

UK, Ireland & Germany Denmark Sweden Consolidated Utilization

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32 Fixed Rate Recourse Debt Floating Rate Recourse Debt

FINANCIAL DISCIPLINE

*Based on book values

Committed to maintaining our investment grade credit ratings of BBB (high) by DBRS and BBB+ by S&P

Total Recourse Debt*

as at March 31, 2017

Consolidated Net Debt to Total Capitalization

Covenant: Max 65%

~30% ~70% 0% 10% 20% 30% 40% 50% 60% 70%

2012 2013 2014 2015 2016 Q1 2017

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Bulk Liquid Storage

($246 million)

Oil Sands Transportation

($779 million)

Conventional Oil Pipelines

($365 million)

NGL Processing

($435 million)

INTER PIPELINE CREDIT STRENGTH

98% 60% 30% 95% Investment Grade Revenue (2016)* Non–Investment Grade Revenue (2016)

14 customers Initial contract term 20+ years 100+ producers Typical exposure

  • f 55 days

~135 customers Average contract length of ~2 years 20+ customers Average contract length of ~7 years

*IPL’s Canadian operations include investment grade counterparties or contractual rights to obtain a guarantee from an investment grade parent; IPL’s European operations include subsidiaries of investment grade parents where IPL typically has the contractual right to customary security; includes Williams Canada acquisition from September 23, 2016 – December 31, 2016

Over 80% of Inter Pipeline’s revenue is sourced from investment grade entities*

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$0 $200 $400 $600 $800 $1,000 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2044

MTN MATURITY PROFILE

Manageable debt maturity profile limits refinancing risk

$ Million Weighted average: cost of debt of ~3.6%; maturity of ~9 years

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EBITDA BY BUSINESS SEGMENT

$ Million $0 $200 $400 $600 $800 $1,000 $1,200 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016

Oil Sands Transportation Conventional Oil Pipelines Bulk Liquid Storage NGL Processing

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EBITDA BY CONTRACT TYPE

*Original Cold Lake TSA based on modified cost of service contract as detailed in IPL’s AIF; see forward–looking information

Cost of Service

No volume or commodity price exposure and flow-through of

  • perating costs*

Fee Based

Volume & operating cost exposure but no commodity price risk

Commodity Based

Volume and commodity price exposure

0% 10% 20% 30% 40% 50% 60% 70%

2011 2013 2015 Q1 2017

0% 10% 20% 30% 40% 50% 60% 70%

2011 2013 2015 Q1 2017

0% 10% 20% 30% 40% 50% 60% 70%

2011 2013 2015 Q1 2017

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LOOKING FORWARD

  • Solid track record of increasing

shareholder value

  • Continued focus on developing

potential growth opportunities

  • Cost of service contracts expected

to continue to generate majority of future cash flow

  • Fee based and cost of service cash

flow alone should support future dividends

  • Well positioned to sustain

dividends with upside growth potential

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CONTACT INFORMATION

SUITE 3200, 215 – 2ND STREET SW CALGARY, ALBERTA T2P 1M4 PHONE: 1 866 716 7473 PHONE: (403) 290 6000 FAX: (403) 290 6090 WEB: INTERPIPELINE.COM INVESTORRELATIONS@INTERPIPELINE.COM