Alaska Analyst & Investor Update J U L Y 1 6 , 2 0 1 8 - - PowerPoint PPT Presentation

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Alaska Analyst & Investor Update J U L Y 1 6 , 2 0 1 8 - - PowerPoint PPT Presentation

Alaska Analyst & Investor Update J U L Y 1 6 , 2 0 1 8 Cautionary Statement The following presentation includes forward-looking statements. These statements relate to future events, such as anticipated revenues, earnings, business


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SLIDE 1

Alaska Analyst & Investor Update

J U L Y 1 6 , 2 0 1 8

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SLIDE 2

Cautionary Statement

The following presentation includes forward-looking statements. These statements relate to future events, such as anticipated revenues, earnings, business strategies, competitive position or other aspects of our operations, operating results or the industries or markets in which we operate or participate in general. Actual outcomes and results may differ materially from what is expressed or forecast in such forward-looking statements. These statements are not guarantees of future performance and involve certain risks, uncertainties and assumptions that may prove to be incorrect and are difficult to predict such as operational hazards and drilling risks; potential failure to achieve, and potential delays in achieving expected reserves or production levels from existing and future oil and gas development projects; unsuccessful exploratory activities; difficulties in developing new products and manufacturing processes; unexpected cost increases or technical difficulties in constructing, maintaining or modifying company facilities; international monetary conditions and exchange rate fluctuations; our ability to complete the sale of our announced dispositions on the timeline currently anticipated, if at all; the possibility that regulatory approvals for our announced dispositions will not be received on a timely basis, if at all, or that such approvals may require modification to the terms of our announced dispositions or our remaining business; business disruptions during or following our announced dispositions, including the diversion of management time and attention; our ability to liquidate the common stock issued to us by Cenovus Energy at prices we deem acceptable, or at all; the ability to deploy net proceeds from our announced dispositions in the manner and timeframe we currently anticipate, if at all; potential liability for remedial actions under existing or future environmental regulations or from pending or future litigation; limited access to capital or significantly higher cost of capital related to illiquidity or uncertainty in the domestic or international financial markets; general domestic and international economic and political conditions, and changes in tax, environmental and other laws applicable to ConocoPhillips’ business; the stability and competitiveness of our fiscal framework; and other economic, business, competitive and/or regulatory factors affecting ConocoPhillips’ business generally as set forth in ConocoPhillips’ filings with the Securities and Exchange Commission (SEC). We caution you not to place undue reliance on our forward-looking statements, which are only as of the date of this presentation

  • r as otherwise indicated, and we expressly disclaim any responsibility for updating such information.

Use of non-GAAP financial information – This presentation may include non-GAAP financial measures, which help facilitate comparison of company

  • perating performance across periods and with peer companies. Any non-GAAP measures included herein will be accompanied by a reconciliation to

the nearest corresponding GAAP measure either within the presentation or on our website at www.conocophillips.com/nongaap. Cautionary Note to U.S. Investors – The SEC permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable and possible

  • reserves. We use the term "resource" in this presentation that the SEC’s guidelines prohibit us from including in filings with the SEC. U.S. investors are

urged to consider closely the oil and gas disclosures in our Form 10-K and other reports and filings with the SEC. Copies are available from the SEC and from the ConocoPhillips website.

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SLIDE 3

Opening Comments

R YA N L A N C E Chairman & CEO

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SLIDE 4

Strategy Hitting on All Cylinders

Value Proposition Principles Disciplined Priorities

Invest capital to sustain production and pay existing dividend 1st

PRIORITY

2nd

PRIORITY

RETURNS Strong Balance Sheet Diverse, Low CoS Portfolio Capital Flexibility Low Sustaining Price

Financial Strength Growing Distributions Disciplined Per- Share CFO Expansion

1By year-end 2018.

Our Unique Characteristics

5

Clear, measurable plan to deliver superior returns to shareholders

Annual dividend growth 3rd

PRIORITY

Reduce debt to $15B1; target ‘A’ credit rating 4th

PRIORITY

20-30% of CFO total shareholder payout annually 5th

PRIORITY

Disciplined investment for CFO expansion

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SLIDE 5

ConocoPhillips’ Peer-Leading Position in Alaska

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50 100 150 200 250 300 MBOED 200 400 600 800 1,000 1,200 1,400 1,600 1,800 MMBOE 200 400 600 800 1,000 1,200 1,400 1,600 1,800 Thousand Net Acres

Largest Producer1 Most Reserves2 Largest Acreage Holder3

Peers include: BP, Caelus, ENI, Hilcorp and XOM.

1Source: Wood Mackenzie, 2018 FY estimate, adjusted to reflect impact of 2018 ConocoPhillips acquisitions. 2Source: Wood Mackenzie, adjusted to approximate oil reserves as of 01/01/18 and reflect impact of 2018 ConocoPhillips acquisitions. 3Source: Reports from Bureau of Land Management & Alaska Department of Natural Resources dated 05/17/18 and 06/04/18, respectively. Only includes acreage position for federal and state lands. Incorporates

ConocoPhillips internal data to reflect impact of Kuparuk acquisition.

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SLIDE 6
  • Uncompetitive tax structure
  • Declining production profile
  • High cost of supply
  • Limited investment
  • Focus on Lower 48 unconventionals

2013 Outlook for Asset

2013 Alaska Outlook: Facing Headwinds

7

ConocoPhillips’ Alaska Outlook

2013

2013 Outlook 100 200 300 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 Production (MBOED)

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SLIDE 7

Current Outlook: Strong Future Spurred by Tax Changes & CoS Focus

8

100 200 300 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028

1Assumes a stable and competitive fiscal framework, excludes 2018 acquisitions, assumes no change to current working interest and excludes Alaska North Slope gas sales.

Current Outlook 2013 Outlook

  • Senate Bill 21 improved fiscal framework
  • Technological advancements and innovations

target new and bypassed resources

  • Comprehensive effort to capture value from legacy

fields and infrastructure

  • Renewed focus on exploration yields early success
  • Company-wide focus on lowering cost of supply

and shift to liquids has made Alaska competitive within the portfolio

Drivers of Transformation ConocoPhillips’ Alaska Outlook1 2013 vs. Current (excluding 2018 acquisitions)

100 200 300 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028

ConocoPhillips’ Alaska Outlook1 2013 vs. Current (including 2018 acquisitions)

1Assumes a stable and competitive fiscal framework, includes impact of 2018 acquisitions at working interests of: Western North Slope = 100% / Kuparuk = ~95%, and excludes Alaska North Slope gas sales.

Production (MBOED)

supported by recent strategic transactions

STRENGTHENED OUTLOOK

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SLIDE 8

Our Alaska Plan is Good for All Stakeholders

9 ► Drives peer-leading low

sustaining price

► ConocoPhillips provided

35% of State of Alaska’s petroleum revenue ‛13-‛17

► Realized price similar to

Brent

► Generates profitable growth

from diversified investments

► Provides low cost of supply

investment opportunities

► Delivers competitive cash

and earnings margins

► Integrated value chain

provides access to multiple markets

► Offers significant

exploration running room

► >20,0001 jobs created by

  • ur activity

► Impactful community

investment & volunteerism

► Priority on environmental,

social and governance stewardship

1Source: The Role of the Oil and Gas Industry in Alaska’s Economy; The McDowell Group; May 2017.

► Leverages ownership in

existing infrastructure

Aligns with ConocoPhillips’ Strategy Supports Alaska’s Economy Creates Value for Shareholders

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SLIDE 9

Today’s Agenda

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Our Future in Alaska Our Legacy in Alaska

Al Hirshberg

  • Low cost of supply, low-decline base production
  • Robust inventory of future projects to drive growth
  • Future upside from applied technology and innovation
  • ~$1B/yr capital delivers 225+ MBOED for a decade

Matt Fox

  • 0.5-1.1 BBOE1 of discovered resource2 in Alaska since 2016
  • Willow confirmed as stand-alone hub
  • Willow: $2-3B of capital over 4-5 years required to achieve 1st oil
  • Significant remaining undrilled resource potential

1Gross discovered resource. 2Discovered resources are known accumulations of quantities of oil and gas estimated to exist in naturally occurring accumulations.

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SLIDE 10

Our Legacy in Alaska

A L H I R S H B E R G EVP, Production, Drilling & Projects

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SLIDE 11

Conventional Assets Play Important & Unique Role in Our Portfolio

<$50/BBL Cost of Supply2Resource

(as of Nov. 2017)

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1Excludes exploration resources. 2Cost of supply is the WTI equivalent price that generates a 10 percent after-tax return on a point-forward and fully burdened basis. Fully burdened includes capital infrastructure, foreign exchange, price-related inflation

and G&A. Resource based on Petroleum Resources Management System, developed by industry to classify recoverable hydrocarbons as commercial or sub-commercial to reflect their status at the time of reporting.

3The realized price at which revenues from commodity sales equal costs (operating costs, taxes, general & administrative costs and tariffs) plus capital (base, development, projects and exploration) expenditures.

10 20 30 40 50 Cost of Supply ($/BBL) 15 5 10 Net Resources (BBOE) 34 29 21 13 2015 2018E Costs Capital

55 42

2018E vs. 2015

25% UNDERLYING IMPROVEMENT

ANS Cash-Balanced Price3 ($/BBL)

Conventional Unconventional LNG & Oil Sands

1.6 BBOE

Conventional Resource in AK

0.4 BBOE

Added Through 2018 Acquisitions

2.0 BBOE1

Total Net Captured Resource <$40/BBL CoS

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SLIDE 12

5 10 15 Miles

N AT I O N A L P E T R O L E U M R E S E R V E – A L A S K A

Prudhoe Bay

Non-Operated (WI=36%)

Projects Central Processing Facility (CPF) ConocoPhillips Acreage Trans Alaska Pipeline System (TAPS)

Kuparuk

(WI=~95%)

CPF3 CPF2

Prudhoe Bay

Non-Operated (WI=36%)

Projects Central Processing Facility (CPF) ConocoPhillips Acreage Trans Alaska Pipeline System (TAPS) CPF1

N AT I O N A L P E T R O L E U M R E S E R V E – A L A S K A

Western North Slope

(WI=100%)

CPF3 CPF1 CPF2

N AT I O N A L P E T R O L E U M R E S E R V E – A L A S K A

GMT-2 GMT-1 Alpine Willow Area

Kuparuk

(WI=~95%)

Prudhoe Bay

Non-Operated (WI=36%)

Projects Central Processing Facility (CPF) ConocoPhillips Acreage Trans Alaska Pipeline System (TAPS) CD5

Legacy Position Sets Foundation for Future Growth

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1Estimated pro-forma annualized production including impacts from recent acquisitions.

  • ConocoPhillips operates Kuparuk and Western North Slope (WNS)
  • Operated assets: 4 central processing facilities and 54 drill sites
  • Years of identified inventory in Kuparuk and Western North Slope
  • Exploration renaissance driving westward expansion
  • Estimated 2018 production of ~225 MBOED1; ~40% of State of Alaska’s production

North Slope A L A S K A Valdez Anchorage

NPR-A

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SLIDE 13

1Assumes a stable and competitive fiscal framework, includes impact of 2018 acquisitions, at working interests of: Western North Slope = 100% / Kuparuk = ~95%, and excludes Alaska North Slope gas sales. 1Assumes a stable and competitive fiscal framework , includes impact of 2018 acquisitions at working interests of: Western North Slope = 100% / Kuparuk = ~95%, and excludes Alaska North Slope gas sales. 2ConocoPhillips net production associated with Alaska North Slope gas sales based on the State of Alaska’s timeline, not included in ConocoPhillips production plots.

Compelling Plan Creates Significant Value for 10+ Years

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BASE

  • Low-risk, predictable production
  • Significant improvement in lowering base decline
  • Identified opportunities to sustain cost of supply

reductions

Base 100 200 300 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028

DEVELOPMENT PROGRAMS

  • Multi-year drilling campaigns
  • Numerous drilling technology advancements

underway

  • Pioneering extended-reach drilling (ERD)

Development 100 200 300 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028

PROJECT INVENTORY

  • CD5 led westward expansion to new sites
  • Near-term contribution from GMT & NEWS
  • GMT-1 first oil 2018; GMT-2 first oil 2021
  • Eastern NEWS first oil estimated 2023
  • Additional upside from technology and innovation

Projects 100 200 300 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028

EXPLORATION

Exploration 100 200 300 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028

14

ConocoPhillips' Alaska Outlook1

Production (MBOED)

40 80 120

2025 2029 2033 ANS Gas Sales2 (MBOED)

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SLIDE 14

100 200 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028

  • Extensive enhanced oil recovery expertise with

waterflood and miscible water alternating gas (MWAG) recovery

  • Ongoing gas lift optimization throughout operations
  • Leveraging data analytics to drive MWAG sweep

efficiency, improve gas handling and increase recovery

Base Production: Significant Progress on Lowering Decline Rate

15

Primary Recovery Water Flood MWAG

Average Reservoir Recovery by Method

~15% ~45% ~60%

MWAG INJECTOR PRODUCER MISCIBLE GAS = SOLVENT RESIDUAL OIL BEHIND WATERFLOOD FRONT OIL BANK

Alaska Base Decline Rate Improved to 6%

(Old decline rate ~8%)

Production1 (MBOED)

1Assumes a stable and competitive fiscal framework, includes impact of 2018 acquisitions at working interests of:

Western North Slope = 100% / Kuparuk = ~95%, and excludes Alaska North Slope gas sales.

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SLIDE 15

Base Production: Sustainable Reductions in Cost of Supply

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Lowered Maintenance Cost & Increased Facility Uptime

  • Harnessing organizational

efficiency to improve productivity

  • Goal to level-load activity and

rapidly apply learnings

  • Infrastructure program phased

with development to minimize peaks and valleys

Lower Intervention Costs & Increased Efficiency

1Person = ConocoPhillips employees and contingent workers; BOPD = gross operated barrels. 2Uptime excludes turnarounds.

Achieving Personnel-Driven Productivity Improvements1

2 0 1 5

96

O p e r a t e d B O P D p e r p e r s o n

2 0 1 8

139

O p e r a t e d B O P D p e r p e r s o n

45%

IMPROVEMENT

80% 84% 88% 92% 96% 100% 50 100 150 200 250 2014 2015 2016 2017 Facility Uptime2 Operated Maintenance Capital ($MM) 80% 84% 88% 92% 96% 100% 50 100 150 200 2014 2015 2016 2017 Well Uptime2 Well Intervention Cost ($MM)

50% REDUCTION

IN COST

HISTORIC HIGH

WELL UPTIME

>50% REDUCTION

IN COST

HIGH

OVERALL UPTIME

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SLIDE 16

Coiled Tubing Drilling: Targets Extensive Inventory of Bypassed Oil

  • Driven by 4D seismic and high-resolution simulation
  • Attractive 10-year portfolio with average cost of

supply of ~$30/BBL

  • Safe and predictable operations with continuous

efficiency improvements

17

2014 1Q 2018

Average Rate of Penetration (ft/day)

~2X

FASTER

Example: Kuparuk Octa-Lateral

6350 6375 6400 6375

Example: Kuparuk Octa-Lateral Well Path

~20% OF CONOCOPHILLIPS ALASKA PRODUCTION

developed with coiled tubing drilling

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SLIDE 17

Old Technology New Technology

Drilling Technology Advancements: Higher Recovery, Lower CoS

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14K ft 30K ft 30K ft

5 ft sands

New Technology Old Technology

Achieving Cost & Time Savings

Old Technology New Technology

~5X

INCREASE

More Footage of Reservoir Drilled

~30%

DECREASE Extending Our Reach

with Managed Pressure Drilling

Threading the Needle

with Geo-Steering

Drill & Case in One Run

with Steerable Drilling Liners

Accessing More Reservoir

with Multi-Laterals

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SLIDE 18

Successful CD5 Execution: Leading the Way to NPR-A

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CD5 Expansion Drives Higher Production (BOPD)

  • Completed on budget, ahead of schedule and

achieved higher initial and overall production rates

  • Accessed reservoir extending beyond seismic

resolution

  • North American record-setting well lengths

and multi-laterals

55% Reduction in CD5 Cost of Supply ($/BBL)

66 36 30

10 14 6 6 FID Sanction Development Optimization Improved Well Performance Cost Efficencies FID Scope Expansion Efficiencies Expansion

CD5 Achieves Peak Rates1 for Alaska (BOPD)

1Monthly average gross oil volumes derived from public AOGCC information.

2,000 4,000 6,000 8,000 10,000 12,000 2015 2016 2017 2018 CD5 wells FID Scope Expansion FID Sanction 10,000 20,000 30,000 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024

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SLIDE 19

44 31 5 5 3 FID Facility Cost Production Optimization Operating Cost ERD Program Outlook

resource to be developed with ERD

>100 MMBOE Extended-Reach Drilling: Maximize Recovery, Minimize Footprint

  • Unique solution for minimizing footprint in arctic environment
  • Allows utilization of existing gravel pads to reach new resource
  • Taking delivery of new-build ERD rig in 2020
  • Largest mobile land rig in North America
  • Capable of drilling more than 7 miles away from the pad
  • Compatible with DEEP1 drilling automation technology

65-Acre Gravel Pad

(1970)**

12-Acre Gravel Pad

(2016)**

12-Acre Gravel Pad

(Future ERD)** Drilling Area Accessible from Pads ~3 sq. miles ~55 sq. miles ~154 sq. miles

Alaska North Slope Reduced Footprint*

*Assumes similar reservoir depth **1970 drilling radius ~ 5,000 ft vs. 2016 drilling radius ~ 22,000 ft vs. future ERD radius ~ 37,000 ft

30% Reduction in Cost of Supply ($/BBL)

20 Future ERD ~37,000’ 2016 ~22,000’ 1970 ~5,000’

Manhattan Bronx Brooklyn Queens

1DEEP (Drilling Execution Efficiency Platform) is proprietary ConocoPhillips drilling technology.

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SLIDE 20

2018 2020 2022 2024 2026 2028

GMT- 2 ENEW S GMT- 1 1H NEWS

Identified Future Inventory: Low-Risk, Multi-Year Opportunities

21

  • Extensive inventory driven by fiscal framework improvement,

cost of supply reductions, technology and innovation

  • Large portfolio of development programs and projects
  • Significant reduction in minimum economic size due to
  • Infrastructure access and spare capacity
  • Applied learnings across operations

Alaska Operated Resource Opportunity Pipeline (Excluding Exploration)

Western North Slope

1Assumes a stable and competitive fiscal framework, includes impact of 2018 acquisitions at working interests of: Western North Slope = 100% / Kuparuk = ~95%, and excludes Alaska North Slope gas sales.

  • ver the next decade

~0.8 BBOE1 RESOURCE DEVELOPED

Development Drilling 1-2 Rotary Rigs & Coiled Tubing Drilling 1H NEWS Kuparuk Eastern NEWS Development ERD Rig Rotary Rig & Coiled Tubing Drilling Extended-Reach Drilling Development Drilling Dev Drilling GMT-1 GMT-2 Development Development Drilling Project 1st oil Dev Drilling

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SLIDE 21

100 200 300 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028

Upside Potential: Technology & Innovation is Still in Early Innings

Longer Laterals Enhanced Recovery Thin-Bed Reservoirs Multi-Laterals Ongoing Efficiency Improvements Reservoirs Within Reach 4D Seismic Production Technologies

ConocoPhillips’ Alaska Outlook1 Numerous Technology & Innovation Applications Can Drive Additional Upside Above Outlook

Production (MBOED) Development Projects Base

to deliver 225+ MBOED

~$1B/YEAR CAPITAL

1Assumes a stable and competitive fiscal framework, includes impact of 2018 acquisitions at working interests of: Western North Slope = 100% / Kuparuk = ~95%, and excludes Alaska North Slope gas sales.

22

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SLIDE 22

100 200 300 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028

Upside Potential: Exploration is a Whole New Ballgame

Development Projects Exploration Base

1Assumes a stable and competitive fiscal framework, includes impact of 2018 acquisitions at working interests of: Western North Slope = 100% / Kuparuk = ~95%, and excludes Alaska North Slope gas sales. 2Gross discovered resource in Alaska since 2016.

Production (MBOED)

discovered resource

500 MMBOE – 1.1 BBOE2

Longer Laterals Enhanced Recovery Thin-Bed Reservoirs Multi-Laterals Ongoing Efficiency Improvements Reservoirs Within Reach 4D Seismic Production Technologies

Numerous Technology & Innovation Applications Can Drive Additional Upside Above Outlook ConocoPhillips’ Alaska Outlook1

23

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SLIDE 23

Our Future in Alaska

M AT T F O X EVP, Strategy, Exploration & Technology

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SLIDE 24

NPR-A Discoveries Open New Westward Frontier

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Pre-2015 2015 2016 2017 2018 2019+ Pre-2015 2015 2016 2017 2018 2019+ Pre-2015 2015 2016 2017 2018 2019+

  • Industry chases deeper Jurassic targets
  • ConocoPhillips evaluates NPR-A Brookianpotential

Kuparuk

GMT-2 GMT-1 CPF1 CPF2

N AT I O N A L P E T R O L E U M R E S E R V E – A L A S K A

Western North Slope

Alpine CPF3

Prudhoe Bay

Trans Alaska Pipeline System (TAPS) Projects Central Processing Facility (CPF) ConocoPhillips Acreage CD5

Willow

Discoveries

  • Willow discovery with identified upside
  • Acquired new 3D CSI seismic

Kuparuk

GMT-2 GMT-1 CPF1 CPF2

N AT I O N A L P E T R O L E U M R E S E R V E – A L A S K A

Western North Slope

Alpine CPF3

Willow

Prudhoe Bay

Trans Alaska Pipeline System (TAPS) Projects Discoveries Central Processing Facility (CPF) ConocoPhillips Acreage CD5

  • Acquired additional ~600M net acres

for ~$30/acre

  • ConocoPhillips increases working

interest in Western North Slope to 100%

West Willow

Kuparuk

GMT-2 GMT-1 CPF1 CPF2

N AT I O N A L P E T R O L E U M R E S E R V E – A L A S K A

Western North Slope

Alpine CPF3

Willow

Trans Alaska Pipeline System (TAPS)

Prudhoe Bay

Projects Discoveries Central Processing Facility (CPF) ConocoPhillips Acreage CD5

  • Executed largest E&A program since 2002
  • Appraised Willow; explored for upside

Kuparuk Prudhoe Bay

N AT I O N A L P E T R O L E U M R E S E R V E – A L A S K A

Western North Slope

Undrilled Prospects Trans Alaska Pipeline System (TAPS) Projects Discoveries Central Processing Facility (CPF) ConocoPhillips Acreage GMT-2 GMT-1 CPF1 CPF2

West Willow

Alpine CPF3

Willow

North Slope

A L A S K A

Valdez Anchorage NPR-A

CD5

  • 0.5 – 1.1 BBOE gross discovered resource
  • 75% of the play remains to be explored

5 10 15 Miles

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SLIDE 25

Testing the Brookian Topset Play

26 Sandy Basin Floor Turbidite Fan Beach Sands Delta Sands River Sands North

Exploration Target Brookian Discovery Existing Jurassic Fields

Willow West Willow GMT-2 Alpine GMT-1 3,000

Vertical Depth (feet)

5,000 7,000 9,000 ConocoPhillips Proprietary Seismic Data Narwhal

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SLIDE 26

Arctic Expertise Enabled Efficient, Successful ‘18 Exploration Program

  • Unique arctic expertise enabled successful

program completion in winter operations window

  • Shallow targets (~4,000 ft) allowed multi-

well program

  • Achieved efficient de-risking of Willow

resource potential

  • Initial Narwhal trend exploration identified

resource upside

  • Activities supported by 3 drilling rigs, 3 well

test units, 2 ice road teams and seismic crew

  • 370,000 total hours worked with no injuries

Central Processing Facility Projects Exploration and Appraisal wells

Alpine GMT-2 GMT-1 Putu Stony Hill

Ice Roads

Ice Roads

  • 58 miles total, 35 ft. wide
  • No lasting impact

CSI Seismic

  • 250 sq. miles of 3D CSI seismic

Greater Willow Exploration & Appraisal

  • 4 wells, 3 well tests
  • 16,100 ft. drilled & 148 ft. cored

<$1/BBL

finding costs

27 5 10 15 Miles CD5

Narwhal Exploration

  • 2 wells, 2 well tests
  • 22,600 ft. drilled, 152 ft. cored
  • Multiple targets
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SLIDE 27

2018 Exploration Program Confirms Stand-Alone Hub at Willow

28

Greater Willow Area

  • 2018 Willow appraisal activities and analysis:
  • Confirmed oil-filled reservoir with 3 new appraisal wells and 3 flow tests
  • API viscosity range: 41° to 44°
  • Facility-limited vertical test rate ~1,000 BOPD
  • Appraisal results combined with CSI data indicate more potential
  • n-trend resource to north and south
  • Additional oil discovery at West Willow creates possibility for tie-back

to Willow hub

  • 2019 Greater Willow Area appraisal season needed to optimize

development plan

current discovered resource

400 – 750 MMBOE1

2018 Well 2018 Well Test

Preliminary Discovered Resource Range Increased

West Willow 1 T7 T2 T6 T9 T8 5 10 15 Miles Willow Discovery Well

1Gross discovered resource in Alaska since 2016.

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SLIDE 28

Willow Development: Optimize Based on Cost of Supply

  • Entering pre-FEED to size development concept
  • Horizontal MWAG development from inception
  • $2-3B of capital over 4-5 years required to achieve 1st oil
  • Multiple years of development drilling post-1st oil
  • Cost of supply <$40/BBL

1st oil 2024-2025

PLANNING FOR FID IN 2021

Optimize Facility Sizing & Installation Facility & Drill Site Design Locating New Construction Materials Gravel Sourcing Appraisal Wells & Technical Evaluation Subsurface Characterization Utilizing Existing Pipeline Network Transportation Infrastructure Commencing Federal Permitting Process Permitting / EIS Process Leveraging Kuparuk for Willow EOR Source Water for Injection Innovative Approach to Lower Cost & Risk Large Module Offload Location

29

Cost of Supply, $/BBL Throughput Capacity

Sweet Spot

Under- Capitalize Over- Capitalize

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SLIDE 29

current discovered resource

100 – 350 MMBOE1 Narwhal Trend: Promising Discoveries with Access to Infrastructure

30

  • Putu and Stony Hill wells were drilled, cored and flow tested on the

Narwhal trend in 2018

  • Prospects originally identified through seismic amplitude mapping
  • Additional appraisal required for both discoveries
  • Multiple development options possible
  • Ability to leverage legacy infrastructure makes these commercially

attractive opportunities

Putu 2A

Putu Seismic Amplitude

2018 Exploration Bottom Hole Locations Central Processing Facility Projects Discoveries 2018 Well Tests

1Gross discovered resource in Alaska since 2016.

Alpine GMT-2 GMT-1 Stony Hill Putu 2/2A 5 10 15 Miles CD5

Narwhal Trend

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SLIDE 30

exploration upside

75% PORTFOLIO UNDRILLED Significant Future Exploration & Appraisal Planned

31

Greater Willow Appraisal

  • Evaluate horizontal well performance
  • Determine lateral reservoir connectivity
  • Appraise West Willow

Narwhal Appraisal

  • Verify recoverable volumes
  • Evaluate well performance

2019 Program Focused on Existing Discoveries Resolve Remaining Uncertainties to Sanction 2020+ Program Focused on Remaining Potential Test Full Prospect Inventory

Projects Discoveries Central Processing Facility ConocoPhillips Acreage Undrilled Prospects N A T I O N A L P E T R O L E U M R E S E R V E – A L A S K A

Western North Slope

5 10 15 Miles

GMT-2 GMT-1

West Willow

Alpine

Willow

1Gross discovered resource in Alaska since 2016.

discovered resource

500 MMBOE – 1.1 BBOE1

CD5

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SLIDE 31

100 200 300 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028

Compelling Alaska Plan Creates Significant Value for 10+ Years

32

ConocoPhillips’ Alaska Outlook1

  • High-quality, low cost of supply source of growth for

ConocoPhillips

  • Realized price similar to Brent
  • Experienced operator with differential arctic capability
  • Existing infrastructure within a world-class

hydrocarbon province

  • Transformation driven by competitive fiscal

framework, technology and exploration renaissance

  • 2.0 BBOE net of <$40/BBL cost of supply resource in

legacy Alaska assets

  • 0.5 – 1.1 BBOE gross of discovered resource since 2016

with 75% of play undrilled

  • Continue to unlock Alaska’s energy potential for years

to come

Aligns with ConocoPhillips’ Strategy – Supports Alaska’s Economy – Creates Value for Shareholders

Production (MBOED)

1Assumes a stable and competitive fiscal framework, includes impact of 2018 acquisitions at working interests of: Western North Slope = 100% / Kuparuk = ~95%, and excludes Alaska North Slope gas sales.

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SLIDE 32

Question & Answer Session