2018 northern border customer meetingnorthernborder.com/docs/customermtgweb.pdf · for discussion...

2018 Northern Border Customer Meeting

April 12, 2018

Welcome

Bill Fonda

Account Director, Marketing & Business Development

For Discussion Purposes – Confidential Communication3

• Welcome – Bill Fonda

• Safety Moment

• Organizational Update – Brandon Anderson

• TransCanada’s Role in North America’s Energy Future – Brandon Anderson

• Commercial Update – Bill Fonda

• Operations Update – Paul Oliver

• Marketing Fundamentals – Colin Strom

• NGTL & Foothills Pipelines Update – Candice Engel

• Break

• Guest Speaker – Dennis Gartman

• Closing and Adjourn

Agenda


Disclaimer: Forward Looking Information

This presentation includes certain forward looking information, including future oriented financial information or financial outlook, which is intended to help current and potential investors understand management’s assessment of our future plans and financial outlook, and our future prospects overall. Statements that are forward-looking are based on certain assumptions and on what we know and expect today and generally include words like anticipate, expect, believe, may, will, should, estimate or other similar words.

Forward-looking statements do not guarantee future performance. Actual events and results could be significantly different because of assumptions, risks or uncertainties related to our business or events that happen after the date of this presentation. Our forward-looking information in this presentation includes statements related to: future dividend growth, the future growth of our core businesses.

Our forward looking information is based on certain key assumptions and is subject to risks and uncertainties, including but not limited to: our ability to successfully implement our strategic initiatives and whether they will yield the expected benefits, the operating performance of our pipeline and energy assets, economic and competitive conditions in North America and globally, the availability, demand for and price of energy commodities and changes in market commodity prices, the amount of capacity sold and rates achieved in our pipeline businesses, the amount of capacity payments and revenues we receive from our energy business, regulatory decisions and outcomes, outcomes of legal proceedings, including arbitration and insurance claims, performance and credit risk of our counterparties, changes in the political environment, changes in environmental and other laws and regulations, construction and completion of capital projects, labour, equipment and material costs, access to capital markets, interest, inflation, tax and foreign exchange rates, including the impact of U.S. tax reform legislation, weather, cyber security, technological developments and economic conditions in North America as well as globally. You can read more about these risks and others in our Fourth Quarter 2017 Financial Highlights release and 2017 Annual Report filed with Canadian securities regulators and the SEC and available at www.transcanada.com.

As actual results could vary significantly from the forward-looking information, you should not put undue reliance on forward-looking information and should not use future-oriented information or financial outlooks for anything other than their intended purpose. We do not update our forward-looking statements due to new information or future events, unless we are required to by law.

This presentation contains reference to certain financial measures (non-GAAP measures) that do not have any standardized meaning as prescribed by U.S. generally accepted accounting principles (GAAP) and therefore may not be comparable to similar measures presented by other entities. These non-GAAP measures may include Comparable Earnings, Comparable Earnings per Share, Comparable Earnings Before Interest, Taxes, Depreciation and Amortization (Comparable EBITDA), Funds Generated from Operations, Comparable Funds Generated from Operations, Comparable Distributable Cash Flow (DCF) and Comparable DCF per share. Reconciliations to the mostclosely related GAAP measures are included in this presentation and in our Fourth Quarter 2017 Financial Highlights release filed with Canadian securities regulators and the SEC and available at www.transcanada.com.

Organizational Update &

TransCanada’s Role in North America’s Energy Future

Brandon Anderson

Senior Vice President, Commercial – U.S. Gas Pipelines

Organizational Update


U.S. Natural Gas Pipelines

Stanley Chapman III

Executive Vice President & President

Brandon Anderson

Sr. VP, U.S. Commercial

Josh Gibbon

VP, Midstream

James Eckert

Sr. VP, Gas Operations

Richard Prior

VP, U.S. Gas Pipeline Projects


U.S. Commercial

Brandon Anderson

Sr. VP, U.S. Commercial

Millie Moran

VP, U.S. Gas Operations

Jay White

VP, U.S. Rates, Regulatory & Strategy

Russ Mahan

VP, U.S. Business Development

Jas Bertovic

VP, U.S. Commercial Marketing


Short Term Marketing Contacts

Jon Howe

Director, Short Term Marketing

(832) 320-5468

[email protected]

Lonnie Lozano

(832) 320-5679

[email protected]

Sean McDonald

(832) 320-5332

[email protected]

Commercial West Export Market Contacts

Long Term Marketing Contacts

Bill Fonda

(402) 492-7430

[email protected]

Colin Strom

(402) 492-7419

[email protected]

Dick Shepherd

(402) 492-7431

[email protected]

Jas Bertovic

VP, U.S. Commercial Marketing

(832) 320-5911

[email protected]

TransCanada’s Role in North America’s Energy Future


TransCanada Today

One of North America’s Largest Natural Gas Pipeline Networks• ~57,100 miles of pipeline• ~653 Bcf of storage capacity• ~23 Bcf/d or 25% of continental

demand

Premier Liquids Pipeline System• 3,000 miles of pipeline• 555,000 b/d or 20% of Western

Canadian exports

Large Private Sector Power Generator• 11 power plants, 6,100 MW• Primarily long-term contracted assets

Enterprise Value ~$100 billion*

*$CAD (2018)


TransCanada’s U.S. Pipeline Assets

Size and Scale

• ~31,000 miles of pipeline

• ~548 Bcf of storage capacity

• ~20% of all U.S. deliveries

• ~2,800 employees

• Assets across 37 states

Strategic Position• Pre-eminent position in lowest cost

supply basins

• Multiple access points to key trading

and storage hubs in the Midwest

• Traditional LDC markets across U.S.

• LNG, power generation, and key

interconnects

• Iroquois & PNGTS provide strategic

connectivity in northeast

• ~40% of TransCanada EBITA from U.S.

Gas by 2019


15MMB/d

180 Bcf/d

Source: IEA – World Energy Outlook 2017, New Policies Scenario*Metric tonnes of coal equivalent

300Mtce*

125GW

2800GW

Global Demandneeds for all energy sources will increase through 2040!

http://www.google.ca/url?sa=i&rct=j&q=&esrc=s&source=images&cd=&cad=rja&uact=8&ved=2ahUKEwirpaDah7jZAhVX4mMKHSXmB4wQjRx6BAgAEAY&url=http://www.iconsplace.com/black-icons/wind-turbine-icon&psig=AOvVaw3VZhYtatlYvGJCPtdpvTKc&ust=1519338654570350


20 Bcf/d of U.S. LNG

exports

60% increase in gas

demand for power

8% increase in

petrochemical

demand

North America - Natural Gas Demand

Drivers to 2040

2040U.S. / Canada

Supply: 150 Bcf/d

Demand: 120 Bcf/d*

Exports: 30Bcf/d

Gas demand

increase 6 Bcf/d

Source: IHS Markit – Global Planning Scenarios, 2017*Does not include exports to Mexico and LNG export demand

4 Bcf/d of

Canadian

LNG exports

North Americaself sufficient and capable of being a global gas player


North America has the oil supply to be self sufficient

U.S. exports increasing to ~1.5 MM b/d**

U.S. imports ~6 MM b/d**

0

5

10

15

20

25

30

2000 2016 2030 2040

North American Oil Production

USA Mexico Canada

<$100 MM project size

<$100 MM project size

Source: IHS Markit – Global Planning Scenarios, 2017 and EIA, 2018*Based on 2017 EIA year-end data figures**EIA, January 2018

Bcf/d

North American Oil Supplywe have the oil supply to be self sufficient

Canada exports ~3.8 MM b/d** to U.S.


In

Processing &

Pipeline

Infrastructure

Renewable

GenerationTransmission

& Distribution

Fossil Fuel Production, 30,000, 52%

Renewables6,300 11%

T&D**** 8,500, 14%

Other Low Carbon*** 1,100, 2%

End Use**, 12,000, 21%

Cumulative Global Investment $US Billion to 2040

Production

Energy Efficiency

2016 North American Investment

$120B $40B

Fossil Fuel

Generation

$12B

$60B $50B$60B

Source: IEA – World Energy Investment 2017, New Policies Scenario*$USD 2016 (Real) **End use includes energy consumed directly by users***Low carbon includes geothermal, hydro, and tidal ****Transmission and Distribution

Global Energy Infrastructureinvestment is growing…reaching ~$60 Trillion by 2040*


TransCanadainvestment in indispensable infrastructure


Industry & Societal Trends

Rapid Technological Change• Shifting market dynamics and consumer preferences • May displace existing technology and upend markets • Impacts long-term investment decisions

Opposition• Rising concerns about safety and environmental impacts are adding

time, uncertainty and cost to project development• Implies the need to strive for zero incidents

Regulatory Change • Lengthening approval timelines and changing regulatory expectations • Jurisdictional disputes and litigation• Canada and U.S. bifurcation


Conclusions and questions

Global demand for

energy and all fuels

will increase!

Investment in energy

infrastructure will

grow…

North America has the

opportunity to be the

global supplier of

energy!

Policy, innovation, opposition and access

to capital will determine if we can win.

Conclusions and Questions

Commercial Update

Bill Fonda

Account Director, Marketing & Business Development


• Positioned to serve markets all

across the upper midwest

• Consists of 1,250 miles of

pipeline

• Capacity of ~2.425 Bcf on the

42” line through North Dakota

• Capacity of ~987 MMcf on the

east segment into Chicago

• Consists of a wide variety of

markets ranging from

interstate pipelines, LDC’s, and

power plants

• Volume throughput and

demand remain strong

Northern Border Overview

ND

SD

MN

IA

IL IN

Harper

Chicago

Manhattan

North

Hayden

Port of Morgan

Capacity: 2,200 MMcf

NGPL Point

Capacity

922 MMcf

NNG Point

Capacity

2,200 MMcf

MT

Ventura

AECO

0.3 %


New Interconnects

ND

SD

MN

IA

IL IN

Harper

Chicago

Manhattan

North

Hayden

• Spring Creek

• Southeast Little Missouri

• McGowan

• Youngs Road

• Atalissa

MT

Ventura

AECO

0.3 %

Spring Creek Expansion (WBI)

• Receipt Point

• McKenzie County, North Dakota

• 730 MMcf

• Projected In-Service September 2018

Southeast Little Missouri (Targa)

• Receipt Point

• McKenzie County, North Dakota

• 205 MMcf

• Projected In-Service Q2 2018

Atalissa (MidAmerican)

• Delivery Point

• Muscatine County, Iowa

• 8 MMcf

• Projected In-Service June 2018

McGowan (Horizon Pipeline)

Receipt Point

Grundy County, Illinois

190 MMcf

Projected In-Service November 2018

Youngs Road (ANR)

• Receipt Point

• Will County, Illinois

• 70 MMcf

• Backhaul transportation to Ventura

• Projected In-Service May 2018


• Positioned to serve markets all

across the upper midwest

• Assessing projected supply

growth in strategic basins

• Evaluating NBPL’s capabilities

to meet growth needs

• We appreciate your thoughts

and views on growth prospects

and look forward to continuing

discussions

Business Development Opportunities

ND

SD

MN

IA

IL IN

Harper

Chicago

Manhattan

North

Hayden

Port of Morgan

Capacity: 2,200 MMcf

NGPL Point

Capacity

922 MMcf

NNG Point

Capacity

2,200 MMcf

MT

Ventura

AECO

0.3 %


• Settlement negotiations concluded on October 6, 2017

• Black box settlement

• Rate reductions

• Preservation of contract extension rights

• NBPL must file a new NGA Section 4 rate case by January 1, 2024

• Settlement filed December 4, 2017

• Order approving settlement issued February 23, 2018

• Compliance filing made on March 27, 2018

Rate Case SettlementRP18-234


Rate Case SettlementRP18-234

January 1, 2018 – March 31, 2018

Demand (per 100 miles)

West - $.0272

East - $.0292

Demand (per path)

PofM to Ventura - $.2235

PofM to North Hayden - $.3485

Ventura to North Hayden - $.1250

April 1, 2018 – December 31, 2019


West - $.0256

East - $.0275

Demand (per path)




January 1, 2020 – December 31, 2023


West - $.0250

East - $.0269

Demand (per path)




Operations & Maintenance Update

Paul Oliver

Manager, West Gas Control


• Winter 2017-2018 weather was 5% colder than normal in

Chicago compared to 9% warmer than normal for Winter

2016-2017.

• Northern Border’s peak transmission day occurred on

December 26, 2017 with system deliveries of 2.95 Bcf.

• Throughout 2017, the pipeline ran at a load factor of 99%

through Glen Ullin.

Operational Notes – Winter 2017-2018


2,508,180 2,479,547 2,465,648 2,510,818 2,460,500

777,755663,443 618,769

507,894

844,648

737,866617,011 554,501

456,282

773,275

0

500,000

1,000,000

1,500,000

2,000,000

2,500,000

3,000,000

Nov-17 Dec-17 Jan-18 Feb-18 Mar-18

Dth

Flow Past Glen Ullin Flow Past Ventura Flow Past Harper

Average Winter Day System Flows


• Like years prior, we continue to reserve April and May for major

planned outages and other capacity impacting events.

• All gas fired compression will take a required, annual maintenance

outage during April and May.

• Individual stations will be offline one at a time in order to minimize

capacity impacts.

Maintenance Schedule – Summer 2018


Maintenance Schedule – April/May 2018

Scheduled Spring OutagesCompressor Station 18 from 4/3 – 4/4Compressor Station 16 from 4/10 – 4/11Compressor Station 04 on 4/11Compressor Station 03 from 4/16 – 4/17Compressor Station 17 from 4/17 – 4/18Compressor Station 09 from 4/18 – 4/19Compressor Station 07 from 4/24 – 4/25Des Plaines from 4/24 – 4/25Compressor Station 03 from 4/26 – 4/27Compressor Station 12 from 4/26 – 4/27Compressor Station 08 from 5/1 – 5/2Compressor Station 14 from 5/1 – 5/2Compressor Station 01 from 5/2 – 5/3Compressor Station 11 from 5/3 – 5/4Compressor Station 02 from 5/16 – 5/17Compressor Station 05 from 5/22 – 5/23Compressor Station 10 from 5/24 – 5/25

Control Upgrade & PT OverhaulsControl upgrades and PT overhauls will be conducted throughout April and May at the following Compressor Stations:

Compressor Station 13 from 4/3 – 4/16Compressor Station 06 from 5/8 – 5/21

Marketing & Fundamentals

Colin Strom

Account Director, U.S. Long Term Marketing & Optimization


• Regional Supply & Demand Forecasts

• Domestic Supply Zone

• Value & Fundamentals Overview

Marketing Fundamentals for NBPL

Regional Supply and Demand Forecasts


Western Canadian Production (Bcf)

Source: Point Logic Energy and Outside Consultants


Bakken Production (Bcf)



Rockies Production (Bcf)



Permian Production (Bcf)



Marcellus & Utica Production (Bcf)



Power Demand in the Central U.S. (Bcf)

0

2

4

6

8

10

12

2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030

PJM

West

ERCOT

MISO

Source: Wood Mackenzie


Southern Demand Pull (Bcf)

0

5

10

15

20

25

30

35

40

2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025

Exports

to Mexico

Corpus

Christi

LNG

Freeport

LNG

Cameron

LNG

Sabine

Pass LNG

TX/LA

Demand

Source: Wood Mackenzie

Domestic Supply Zone


Supply Diversification

Source: Internal Analysis

Canadian84%

Bakken10%

Coal Gasification6%

Rockies0%

Northern Border Receipt Mix

2010

Canadian62%

Bakken25%

Coal Gasification5%

Rockies8%


2014

Canadian57%

Bakken39%

Coal Gasification4%

Rockies0%


2017


Bakken Production ForecastWellhead Wet Gas

Source: JJ Kringstad – North Dakota Pipeline Authority


Domestic Supply Zone – March, 2018

Bakken Interconnects Receipts Meter Capacity

Stateline 94 233

Squaw Creek 71 107

Charbonneau 108 176

Rawson 182 234

Hay Butte 6 50

Spring Creek 400 507

Watford City 41 68

Little Missouri 69 117

Alexander 18 90

Roosevelt 37 57

Killdeer 67 96

Glen Ullin 7 140

Total Bakken 1,100 1,875

Other Domestic Receipts Meter Capacity

Saskana (Omimex) 5 60

Manning (Grasslands) 6 198

Hebron (Dakota Gas) 121 169

Kurtz (Bison) 0 407

Grand Total 1,232 2,709

*Northern Border (MDth)

Source: *Internal Analysis**Point Logic Energy

Production (wet gas) 1943

Flared Gas (12%) 233

Tioga Lateral 83

Pecan Pipeline 153

Shrink 376

**Bakken Activity (MMcf)


Bakken Flaring & Gas Capture Targets

November, 2013 December, 2014 February, 2018

Gas Capture Targets:

Jan 2015: 77%

Apr 2016: 80%

Nov 2016: 85%

Nov 2018: 88%

Jan 2020: 91%

Source: JJ Kringstad – North Dakota Pipeline Authority

Value & Fundamentals Overview


Full Cost AECO Dispatch


Forward Pricing to Ventura/DemarcAECO vs Field/Lower MidContinent


Forward PricingAECO to Ventura/Chicago Values

to Chicago

to Ventura


Peak Summer Weather ForecastJune to August

NOAA

Radiant Solutions

Source: NOAA and Radiant Solutions Weather Services


2018 Maintenance Capacity

All of the current year’s maintenance capacity has been sold

2018 Design Capacity

July-August, 2018

~20 MMcf of Ventura to Chicago

Capacity Subject to ROFR

April, 2019

~50 MMcf of Ventura to Chicago

November, 2019

~15 MMcf of PofM to Brandt

~7 MMcf of PofM to Ventura

NBPL Available Capacity


• Supply fundamentals

• NGTL performance at the eastern gate

• NGTL export enhancements for 2018 and beyond

• Marcellus/Utica flow direction

• Competition for supplies in the south

• TransCanada Mainline contracting

• Park & Loan services

Opportunities & Impacts to Pipeline Values

NGTL & Foothills Pipelines Update

Candice Engel

Manager, Commercial West Markets

Andrea Watters

Account Manager, Exports


Canadian Natural Gas Pipelines

CANDIAN PIPELINE SYSTEMS

• NGTL System

• Canadian Mainline

• Foothills Pipeline

• Trans-Quebec and Maritimes Pipeline

LEADERSHIP

Tracy Robinson, Senior VP Canadian Gas

• Patrick Keys, VP Commercial West

• NGTL System

• Foothills Pipelines

• Stephanie Wilson, VP Commercial East

• Canadian Mainline

• Trans-Quebec and Maritimes Pipeline

• Jawad Masud, VP Commercial Services and Optimization and Design


Commercial West – Organizational Chart

Patrick KeysVice President

Canadian Gas Pipelines, Commercial West

Ashley InnesDirector, Comm-West

Markets, Industry Collaboration & Rates

Candice EngelManager, Exports

Ashley StowkowyAccount Manager,

Exports

Andrea WattersAccount Manager,

Exports

Scott YuleManager, Intra-Alberta Markets

Tammy Manz Manager, Strategy &

Collaboration

Penelope Echenagusia

Manager, Rates

Keith NelsonDirector, Comm-West

Supply & Commercial Development

Blaine TroutManager, Supply

Todd HarperManager, Supply

Glenn SmetheramCAM


WCSB Production Seeking Markets

Midwestern U.S.857 Bcf2.35 Bcf/d20%

Eastern Canada /Northeast U.S.744 Bcf2.04 Bcf/d18%Pacific Northwest /

California787 Bcf2.16 Bcf/d19%

Potential LNGExports

Alberta and B.C.1,822 Bcf4.99 Bcf/d43%

NGTL System Throughput2017 total: 4,210 Bcf2017 daily average: 11.53 Bcf/d

Total 2017 deliveries2017 average daily deliveriesAnnual NGTL throughput


0

5

10

15

20

25

2005 2010 2015 2020 2025 2030

Conventional Gas (Vertical)Deep Basin

Northern Shales

CBM

Montney

Duvernay

Solution Gas

Bcf/d History Forecast

WCSB Supply


NGTL Empress Historic Flows

0

1,000

2,000

3,000

4,000

5,000

6,000

1-Jan 1-Feb 1-Mar 1-Apr 1-May 1-Jun 1-Jul 1-Aug 1-Sep 1-Oct 1-Nov 1-Dec

TJ/

d

2016 2017 2018

LTFP1.5 PJ/d


NGTL McNeill Historic Flows

0

500

1000

1500

2000

2500

1-Jan 1-Feb 1-Mar 1-Apr 1-May 1-Jun 1-Jul 1-Aug 1-Sep 1-Oct 1-Nov 1-Dec

TJ/

d

2016 2017 2018


Empress and McNeill Border Open Seasons


NGTL Mainline Expansions 2018-2021

• ~$7.0 billion of facilities in-service in

2018 through 2021

• 18 compressor units totaling 540 MW

• Approximately 120 km customer specific

pipeline ranging from NPS 16-24

• Approximately 800 km mainline pipeline

ranging from NPS 36-48

NMML Facilities

2019 Facilities

2020 Facilities

2021 Facilities

2018 Facilities


2021 NGTL System Expansion Project

• Approximately 350km

NPS 48 Pipe

• Three 30MW Compressor

Units

• One Control Valve Facility


Expanding WCSB Access to Markets

Gas TransmissionNorthwest

Northern Border

Great Lakes Gas Transmission

Canadian Mainline

PNGTS

Iroquois Gas Transmission

West CoastLNG

LTFP1.5 Bcf/d

West GateExpansions

650 MMcf/d

Basin Expansions550 MMcf/d

East Gate Expansions 1.3 Bcf/d

2.5 Bcf/d of Planned Market Capacity Expansions to 2021*

* 280 MMcf/d of EGAT expansion facilities being finalized.


2017 and 2018 Pipe Integrity Program

2018

20-25 Launcher/Receiver Pairs30-35 Unconventional ILI55-65 Conventional ILI400-500 Post ILI Digs/Repairs

2017

20 Launcher/Receiver Pairs 30 Unconventional ILI77 Conventional ILI530 Post ILI Digs/Repairs

Launcher/Receiver/Mods

Local or no impact

Potential area/export impact

Probable area/export impact

Inline Inspections

Local or no impact

Potential area/export impact

Probable area/export impact


NGTL Daily Operating Plan


EGAT Operational Capability


NGTL Revised 2018 Interim Rates

NGTL System - Transportation Rate Sheet

Revised Interim 2018 Rates (proposed to be effective May 1, 2018)

Receipt Service (3 yr term)

Revised Interim 2018 Rates

Interim 2018 Rates

(Effective May 1, 2017) (Effective January 1,

2018)

Receipt Service $/103m3 ¢//Mcf/d $/103m3 ¢//Mcf/d

FT-R Average Demand Rate (3 year term) 207.20/mo 19.3 203.40/mo 18.9

IT-R Interruptible Rate (based on FT-R Average above)

7.83/d 22.2 7.69/d 21.8

Delivery Service $/GJ/mo ¢/GJ/d $/GJ/mo ¢/GJ/d

FT-D Group 1 Demand Rate (1 year term):

Empress/McNeill 5.38 17.7 5.27 17.3

Alberta-B.C. Border 4.99 16.4 4.89 16.1

Gordondale/Boundary Lake Borders 4.99 16.4 4.89 16.1

Clairmont/Shell Creek/Edson 4.99 16.4 4.89 16.1


All Group 2 Delivery locations 4.99 16.4 4.89 16.1


All Group 3 Delivery locations 5.99 19.7 5.87 19.3

IT-D Group 1 Interruptible Rate:

Empress/McNeill - 19.45 - 19.07

Alberta-B.C. Border - 18.05 - 17.70

Gordondale/Boundary Lake Borders - 18.05 - 17.70

Clairmont/Shell Creek/Edson - 18.05 - 17.70

IT-D Group 2 Interruptible Rate:

All Group 2 Delivery locations - 18.05 - 17.70

• Receipt Point Specific FT-R Rates will vary between the price floor and price ceiling and will be a function of the contract term selected.

• Rates above do not include applicable Abandonment Surcharge.

• These rates do not include a provision for the federal Goods and Services Tax.

• All rates are quoted in Canadian dollars.


TTFP Chair:

Tammy Manz

Manager, Commercial West Collaboration and Strategy

(403) 920-6330

[email protected]

Collaboration Initiatives:

• Rate Design Task Force

• Revenue Requirement

• Delivery Attributes (Transfers)

• System Reliability (Supply)

• Policy and Operational Communication

• Customer Operation Meetings

Collaboration Team


NGTL Customer Connect

• NGTL Customer Connect EventMay 29, 2018The Westin CalgaryMore Details to Follow


Ashley Innes

Director, Commercial West Markets, Industry Collaboration & Rates

(403) 920-2670

[email protected]

Candice Engel

Manager, Commercial West MarketsExport Markets

(403) 920-5623

[email protected]

Commercial West Export Market Contacts

Andrea Watters

Account Manager, Commercial West Export Markets

(403) 920-7956

[email protected]

Ashley Stowkowy

Account Manager, Commercial West Export Markets

(403) 920-5828

[email protected]

2018 northern border customer meetingnorthernborder.com/docs/customermtgweb.pdf · for discussion...

Documents