NYSE: DVN devonenergy.com
Investor Presentation
December 2019
Investor Presentation December 2019 NYSE: DVN devonenergy.com - - PowerPoint PPT Presentation
Investor Presentation December 2019 NYSE: DVN devonenergy.com Devons Competitive Advantage World-class U.S. oil portfolio New Devon Overview Unrivaled acreage position in top basins Multi-decade growth inventory Production: 325
NYSE: DVN devonenergy.com
December 2019
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Investor Presentation
— Unrivaled acreage position in top basins — Multi-decade growth inventory — Top-tier well productivity across all assets
— Aggressively improving cost structure — Growing higher-margin oil production — Positioned for FREE CASH FLOW above $48 WTI
— Committed to return of capital — Capital-efficient per-share growth — Building a fortress balance sheet
25 MBOED (71% OIL)
STACK
121 MBOED (26% OIL)
POWDER RIVER EAGLE FORD
45 MBOED (49% OIL) 127 MBOED (56% OIL)
DELAWARE
Production: 325 MBOED (Q3 2019) Revenue: 74% oil Oil growth rate: 20%-21% in 2019 Multi-decade growth inventory
New Devon Overview
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Investor Presentation
U.S. well productivity showcases asset quality
Source: IHS/Devon. All wells drilled from 2015 through 2019 YTD. Includes operators with more than 150 wells.
2,000 4,000 6,000 2019 Program High-Return Inventory Risked Inventory
(@ $50 WTI) (@ $60 WTI)
High-return inventory diversified across top U.S. basins
Gross operated inventory locations (non-operated locations not included) >20 YEAR INVENTORY
(AT CURRENT DRILLING PACE) STACK Delaware Basin Eagle Ford PRB
6,500 operated locations 4,200 operated locations ~280 operated wells online 15 YEAR INVENTORY
(AT CURRENT DRILLING PACE)
Note: High-return inventory represents locations estimated to generate >20% IRR. Returns based on all-in E&P capital investment, which includes drilling, completion and well-site facilities and flow back.
250 350 450 550 650 750 850 950
PEER AVG.
Top 50 U.S. Producers
SUPERIOR WELL RESULTS ~45%
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Investor Presentation
Q3 2018 Q3 2019
U.S. oil production exceeds guidance
New Devon (MBOD)
148
(Q3 Guide: 141-147)
124
ABOVE MIDPOINT U.S. OIL PRODUCTION
BARRELS PER DAY
Q3 2018 Q4 2018 Q1 2019 Q2 2019 Q3 2019
G&A LOE & GP&T Interest
Improving cost structure expands margins
Per-unit cost (reported) ($/BOE)
$11.86 $14.18
SINCE Q3 2018
Old DVN DVN Today
Efficiencies delivering improved capital outlook
New Devon 2019e E&P capital
$1.83-$1.87
E&P CAPITAL
50%
DELAWARE
20%
STACK
14%
POWDER RIVER
16%
EAGLE FORD
BILLION
Original Guidance ($1.8 - $2.0 billion)
— Strong well productivity drives Q3 oil volumes above guidance — Lowered 2019 capital outlook by $50 million — $780 MM cost savings initiative ahead of plan (80% by YE19)
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Investor Presentation
LOE & GP&T G&A Financing costs
U.S. oil growth
Upstream capital
Updated Guidance
20% – 21%
(vs. 2018)
$7.60 – $7.65
(per BOE)
$460 – $470
($ in millions)
$245 – $255
($ in millions)
$1.83 – $1.87
($ in billions)
Guidance Key Messages
(1) Represents New Devon performance target (excludes Barnett Shale).
(1) (1)
Improvement
15%
Improvement
17%
Improvement
22%
Improvement
$50
Basis Point
550
Million
Improvement
Improv
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Investor Presentation
CAPITAL ALLOCATION PRIORITIES
Maintain base production Pursue high-return growth projects Return excess cash to shareholders Fund dividends
1 2 3 4
WTI PRICE
(ASSUMES $2.50 HENRY HUB)
GREATER ER THAN AN
$50 50 $50 50 $4 $45
(Program funded @ $48 WTI)
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Investor Presentation
S H A R E CO U N T VS . 2 0 1 9 N E W D E V O N A S S E T S E & P C A P I TA L P R O G R A M
D E S I G N E D F O R U LT R A - LO W B R E A K E V E N P R I C I N G
DRIVEN BY LOW-RISK DEVELOPMENT DRILLING
ENHANCING PER-SHARE CASH FLOW GROW TH
Key Messages
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Investor Presentation 0% 2% 4% 6% 8% 10% $- $250 $500 $750 $60 WTI $2.50 HH $50 WTI $2.50 HH
2020e Free Cash Flow ($MM)
(before dividends)
2020e Free Cash Flow Yield
Free Cash Flow Free Cash Flow Yield
$55 WTI $2.50 HH
MILLION MILLION MILLION
FY2020 OUTLOOK
Note: Free cash flow yield assumes market capitalization based on share price as of 11/01/19 multiplied by expected shares outstanding at year-end 2019 (~375 mm shares). Free cash flow represents operating cash flow less total capital requirements before dividends.
OIL GROWTH: 7%-9% BREAKEVEN: $48 WTI
(Assumes $2.50 Henry Hub)
EXCLUDES BARNETT SHALE
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Investor Presentation
$3.0 $3.2 $3.4 $3.6 $3.8 $4.0 $4.2 2019e - 2020e 2019e - 2020e
Original Plan
(2/19/19 Guide)
Oil production remains on track
New Devon 2019-2020 cumulative oil production (MMBO)
Efficiencies driving lower capital requirements
New Devon 2019-2020 cumulative upstream capital ($B)
Current Plan
(11/05/19 Guide) New Devon Cumulative Upstream Capital ($B)
(Cumulative Capital) (Cumulative Capital)
30 45 60 75 90 105 120 2019e - 2020e 2019e - 2020e
Original Plan
(2/19/19 Guide)
Current Plan
(11/05/19 Guide) New Devon Cumulative Oil Production (MMBO)
~$400 MILLION LESS CAPITAL
(VS. ORIGINAL PLAN)
(Cumulative Oil) (Cumulative Oil)
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Investor Presentation
Dedicated to disciplined allocation of capital
$11.0 Billion
Q1 2018 Q2 2018 Q3 2018 Q4 2018 Q1 2019 Q2 2019 Q3 2019 10/31/19 YE 2019e
SHARE COUNT REDUCTION
527 ~375(1) 521 491 459 415
397
(1) Assumes remaining authorization is completed by year-end and incremental shares are repurchased at current share price.
434
Repurchase program accelerates per-share growth
Outstanding basic shares (MM)
Share buyback New Devon capital Debt reduction Dividends
ALLOCATED TO SHAREHOLDER RETURNS & DEBT REDUCTION
Uses of Cash Since 2018
383
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Investor Presentation
Aggressive debt reduction improves financial strength
Net debt(1) ($B)
$10.7 $2.6
12/31/2015 12/31/2016 12/31/2017 12/31/2018 9/30/2019
SINCE 2015
($ in billions) Total debt (GAAP) $4.3 Less cash $1.7 Net debt (Non-GAAP)(1) $2.6 EBITDAX (Non-GAAP)(1)(2) $2.6 Net debt to EBITDAX ratio 1.0x
Low leverage provides competitive advantage
Liquidity 2025 2027 2031 2032 2041 2042 2045
$675 $366 $1,250 $750 $750 $485 $73
Significant liquidity with no near-term debt maturities
Debt maturities ($MM) $4,700
NET DEBT TO EBITDAX
REDUCTION
Liquidity
NO DEBT MATURITIES
SIGNIFICANT FINANCIAL FLEXIBILITY UNTIL 2025
AS OF 9/30/2019
Cash Credit Facility
— $1.7 billion of debt retired YTD — Evaluating next steps for debt reduction program — Potential INTEREST SAVINGS of ~$130 million annually
— Majority of oil and gas volumes protected in Q4 2019 — Targeting ~50% oil & gas production in 2020
(1) Net debt and EBITDAX are non-GAAP measures. Non-GAAP reconciliations are provided in Q3 earnings release materials. (2) Based on last 12 months results from continuing operations.
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Investor Presentation
— Contributing gathering & compression assets — Devon to remain operator of the assets — Receive $100 MILLION cash distribution in Q4 — Partner to fund $40 million of expansion capital
— Data rooms opened in early Q3 — Initial bids RECEIVED in September — Ongoing negotiations with advantaged bidders
— Transaction closed in Q2 2019
DEVON ASSETS DIVESTITURE ASSETS POWDER RIVER STACK DELAWARE EAGLE FORD
ROCKIES CO2 BARNETT SHALE
Q3 Production: 100 MBOED Sales process: Ongoing Q3 Production: 3 MBOED Sales process: Ongoing ACCRETIVE MULTIPLE:
~10x CASH FLOW
SALES PRICE:
CAD $3.8 BILLION CANADIAN HEAVY OIL
CLOSED: Q2 2019
COTTON DRAW
(MIDSTREAM PARTNERSHIP)
Proceeds: $100 million Gathering: 90 miles Compression: 4 stations
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Investor Presentation
DELAWARE BASIN DEVELOPMENT ACTIVITY
POTATO BASIN TODD THISTLE/GAUCHO RATTLESNAKE COTTON DRAW
Upcoming Projects Core Development Area Key 2019 Projects New Mexico Texas Eddy Lea Loving
RECORD WELL PRODUCTIVITY ACHIEVED IN 2019 DEVELOPMENT EFFICIENCIES ACCELERATING
— STACKED PAY position across >250,000 net acres — Acreage resides in economic core of play — Multi-decade growth inventory
— Capital activity diversified across 5 core areas — 8 rigs supported by 2 dedicated frac crews — 2019 activity: ~120 wells expected online
— Q3 net production INCREASED 59% year-over-year — Wolfcamp program continues to build momentum — Per-unit costs to improve by >15% vs. 2018
VanMar (4 wells)
Cotton Draw Unit (4 wells)
Tomb Raider (5 wells)
Cat Scratch Fever 1.0 (10 wells)
Chiles (3 wells)
N Thistle 34 (6 wells)
Bell Lake (5 wells)
Fighting Okra (9 wells)
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Investor Presentation
10% 30% 50% 70% 25 50 75 100 125 150 175 200
Productivity Improvement (2019 vs. 2018) 90 Day Oil IP Rate per 1K lateral, BOD (2019)
PEER AVG. PEER AVG.
APA CVX NBL XOM MTDR FANG PDCE CRZO PRIVATES WPX CXO MRO CDEV OXY EOG COP DVN
Source: IHS, Goldman Sachs Global Investment Research Note: Bubble size represents 2019 wells as a percent of Delaware Basin total
Development focus driving best-in-class wells
90-day oil IPs, BOD vs. improvement in performance (2019 vs. 2018)
— D&C costs decline by 12% in Q3 vs. 2018 ($851 per foot) — Wolfcamp driving capital efficiency improvements (chart) — Lower facility costs to contribute to future cost savings
Drilling and completion efficiencies accelerate
Drilled and completed feet per day (Wolfcamp formation)
820 880 1,180 1,360 2018 Q1 2019 Q2 2019 Q3 2019
65%
COMPLETION IMPROVEMENT
Drilling Completions
45%
DRILLING IMPROVEMENT
900 750 700 625
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Investor Presentation
— Charged reservoir with stacked-pay potential — Large, contiguous units with high working interest (>90%) — 2019 capital activity: ~30 new wells online
— 10-wells offsetting prolific phase 1.0 (targeting 2nd Bone Spring)
— Expect to bring online >30 new wells in 2020 — Activity diversified between Leonard, Bone Spring & Wolfcamp — Several hundred undrilled inventory locations remaining
A VISIBLE LONG-TERM GROWTH PLATFORM
NEW WELLS ONLINE IN 2020
A KEY GROWTH DRIVER IN UPCOMING YEAR
Bone Spring Leonard Wolfcamp
Ko Lanta
2 wells (9,700’ laterals)
Tomb Raider
3 wells (9,900’ laterals)
Boundary Raider
2 wells (9,800’ laterals)
Belloq
5 wells (8,700’ laterals)
Cat Scratch Fever 2.0
10 wells flowing back
Eddy Lea
Cat Scratch Fever 1.0
10 wells (8,300’ laterals)
(Facility constrained rates)
TODD DEVELOPMENT AREA
STRONG GROWTH PLATFORM CAT SCRATCH 2.0 ONLINE
Tomb Raider
4 wells (9,800’ laterals)
Tomb Raider (4,700’ lateral)
IP30: 1,500 BOED
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Investor Presentation
NIOBRARA TYPE LOG
200 ft.
Potential landing zones
C B A
NIOBRARA APPRAISAL SUCCESS CONTINUES STACKED PAY POSITION IN OIL FAIRWAY
POWDER RIVER BASIN NIOBRARA ACTIVITY
Converse
PDU WJ Ranch 22-1X
Conley Draw 9-1X
100 ft.
SDU Tillard 17-1X
ATLAS WEST ATLAS EAST
SSU MLT 16-2X
SDU Tillard 25-1X
(Stacked test with Turner)
Tillard 18-1 spacing test (3 wells)
Niobrara Appraisal Wells Niobrara Spacing Tests Upcoming Niobrara Activity
— Stacked pay position in oil fairway (>300k acres) — Activity targeting multiple intervals across basin — High-margin production (oil mix: 71%)
— Turner program drives operational efficiencies — RAISING 2019 production exit-rate targets — Achieving D&C savings of >$1 million per well
— 8 operated wells online (avg. IP30: 1,300; 87% oil) — Activity includes two successful spacing tests — Potential to DOUBLE Niobrara activity in 2020
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Investor Presentation
— Lighter-spaced projects delivering strong results — Tailoring capital activity to current environment — Evaluating partner opportunities to enhance returns — Substantial long-term inventory optionality
— 10-year drilling inventory with upside potential — Redevelopment & refrac spacing tests in 1H 2020 — Attained cost savings of >$1 MM per well YTD — Q4 2019e net production rate: 50-55 MBOED
STACK DEVELOPMENT ACTIVITY
Key 2019 Activity 2019 Meramec Focus Area
Blaine Kingfisher Canadian
Morning Thunder
(4 wells/DSU)
Everett
(4 wells/DSU)
(1) Normalized for 10,000’ laterals.
EAGLE FORD ACTIVITY
Dewitt Karnes
LAST 12 MONTHS FREE CASH FLOW ($MM) FREE CASH FLOW ($MM)
LAST 12 MONTHS
Key 2019 Activity 2019 Refrac Program Centaur
(5 wells/DSU)
Pickaroon
(4 wells/DSU)
Redevelopment Wells
Lower Eagle Ford Wells (9 wells)
Upcoming Activity >25 Eagle Ford wells Lower Eagle Ford Wells (5 wells)
Gonzales
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Investor Presentation
For additional information see our
2019 Sustainability Report
Key Messages
OVERALL SCORE
DVN’s SCORE: 2 PEER AVERAGE: 4.1
VERSUS PEER AVG.
Devon is rated in the TOP-QUARTILE of its peers
(Highest rating achieved in governance)
Note: Sustainalytics scores and rankings updated 10/21/2019. Peer group comprised of 20 E&P companies.
Devon recently named to the:
Note: ISS scoring scale ranges from 1 to 10. The best score possible is 1. Peer group comprised of 13 E&P companies.
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Investor Presentation
— Unrivaled acreage position in top basins — Multi-decade growth inventory — Top-tier well productivity across all assets
— Aggressively improving cost structure — Growing higher-margin oil production — Positioned for FREE CASH FLOW above $48 WTI
— Committed to return of capital — Capital-efficient per-share growth — Building a fortress balance sheet
25 MBOED (71% OIL)
STACK
121 MBOED (26% OIL)
POWDER RIVER EAGLE FORD
45 MBOED (49% OIL) 127 MBOED (56% OIL)
DELAWARE
Production: 325 MBOED (Q3 2019) Revenue: 74% oil Oil growth rate: 20%-21% in 2019 Multi-decade growth inventory
New Devon Overview
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Investor Presentation
Investor Relations Contacts
Scott Coody Chris Carr
VP, Investor Relations Manager, Investor Relations 405-552-4735 405-228-2496 Email: investor.relations@dvn.com Forward-Looking Statements This presentation includes “forward-looking statements” as defined by the Securities and Exchange Commission (the “SEC”). Such statements include those concerning strategic plans, our expectations and objectives for future operations, as well as other future events or conditions, and are often identified by use of the words and phrases “expects,” “believes,” “will,” “would,” “could,” “continue,” “may,” “aims,” “likely to be,” “intends,” “forecasts,” “projections,” “estimates,” “plans,” “expectations,” “targets,” “opportunities,” “potential,” “anticipates,” “outlook” and other similar
included in this presentation that address activities, events or developments that Devon expects, believes or anticipates will or may
are subject to a number of assumptions, risks and uncertainties, many of which are beyond our control. Consequently, actual future results could differ materially from our expectations due to a number
NGL prices; uncertainties inherent in estimating oil, gas and NGL
Investor Notices
reserves; the extent to which we are successful in acquiring and discovering additional reserves; the uncertainties, costs and risks involved in oil and gas operations; regulatory restrictions, compliance costs and other risks relating to governmental regulation, including with respect to environmental matters; risks related to regulatory, social and market efforts to address climate change; risks related to our hedging activities; counterparty credit risks; risks relating to our indebtedness; cyberattack risks; our limited control over third parties who
insurance covers any losses we may experience; competition for assets, materials, people and capital; our ability to successfully complete mergers, acquisitions and divestitures; and any of the other risks and uncertainties discussed in our Form 10-K and other filings with the
may differ materially from those projected in the forward-looking statements. The forward-looking statements in this presentation are made as of the date of this presentation, even if subsequently made available by Devon on its website or otherwise. Devon does not undertake any obligation to update the forward-looking statements as a result of new information, future events or otherwise. Use of Non-GAAP Information This presentation may include non-GAAP financial measures. Such non-GAAP measures are not alternatives to GAAP measures, and you should not consider these non-GAAP measures in isolation or as a substitute for analysis of our results as reported under GAAP. For additional disclosure regarding such non-GAAP measures, including reconciliations to their most directly comparable GAAP measure, please refer to Devon’s third-quarter 2019 Form 10-Q and other earnings materials at www.devonenergy.com. Cautionary Note to Investors The SEC permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable and possible reserves that meet the SEC's definitions for such terms, and price and cost sensitivities for such reserves, and prohibits disclosure of resources that do not constitute such reserves. This presentation may contain certain terms, such as high-return inventory, potential locations, risked and unrisked locations, estimated ultimate recovery (EUR), exploration target size and other similar terms. These estimates are by their nature more speculative than estimates of proved, probable and possible reserves and accordingly are subject to substantially greater risk of being actually realized. The SEC guidelines strictly prohibit us from including these estimates in filings with the SEC. Investors are urged to consider closely the disclosure in our Form 10-K, available at www.devonenergy.com. You can also obtain this form from the SEC by calling 1-800-SEC-0330 or from the SEC’s website at www.sec.gov.
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Investor Presentation
Q3 2019 - ASSET DETAIL NEW DEVON DELAWARE STACK POWDER RIVER EAGLE FORD(1) OTHER
PRODUCTION Oil (MBbl/d)
148 70 32 18 22 6
NGL (MBbl/d)
79 28 37 2 11 1
Gas (MMcf/d)
588 167 317 28 75 1
Total (MBoe/d)
325 127 121 25 45 7
ASSET MARGIN (per Boe) Realized price
$30.32 $33.48 $22.07 $41.20 $35.10 $46.41
Lease operating expenses
($3.73) ($4.17) ($2.08) ($7.28) ($3.20) ($15.06)
Gathering, processing & transportation
($3.74) ($2.20) ($5.05) ($2.07) ($5.93) ($0.29)
Production & property taxes
($2.06) ($2.69) ($0.86) ($4.73) ($1.95) ($3.30)
Field-level cash margin
$20.79 $24.42 $14.08 $27.12 $24.02 $27.76
CAPITAL INVESTMENT ($MM) Operated capital
$444 $257 $59 $85 $38 $5
Non-operated capital
$75 $5 $8 $4 $52 $6
Total capital investment
$519 $262 $67 $89 $90 $11
.CAPITAL ACTIVITY Operated development rigs (avg.)
19 9 2 4 4
Operated frac crews (avg.)
7 3 1 1 2
Operated spuds
74 38 4 14 18
Operated wells tied-in
68 34 16 18 –
Average lateral length (based on wells tied-in)
9,600’ 9,700’ 9,600’ 9,500’ N/A
Operated working interest (based on wells tied-in)
79% 87% 56% 81% N/A
(1) Includes partner activity.
For additional modeling stats and updated guidance see our Q3 earnings release tables
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Investor Presentation
HEALTH & SAFETY METRICS 2016 2017 2018
Safety Performance - Total Recordable Incident Rate (TRIR) 0.41 0.60 0.50 Employee TRIR 0.36 0.57 0.31 Employee Hours (millions) 8.9 6.7 7.0 Contractor TRIR 0.44 0.63 0.54 Contractor Hours (millions) 16.2 20.8 29.4
ENVIRONMENTAL METRICS 2016 2017 2018
Direct GHG Emissions (million tonnes CO2e)(1) 5.20 5.37 5.65 Direct and Indirect GHG Emissions (million tonnes CO2e)(1) 5.77 5.94 6.30 GHG Emissions Intensity (tCO2e/MBOE)(1) 66.53 67.95 78.11 Methane Emissions (million tonnes CO2e)(1) 1.51 1.30 1.22 Methane Emissions Intensity (tCO2e/MBOE)(1) 15.27 12.91 12.27 U.S. Methane Emissions Intensity (% of natural gas produced)(2) 0.315% 0.309% 0.324% Indirect Emissions - Electricity Use (million tonnes CO2e)(1) 0.57 0.57 0.65 Energy Used - Fuel and Electricity Use (trillion BTU)(1) 81.12 85.70 73.49 U.S. Water Usage (million bbl) 25.40 51.32 67.50 U.S. Water Usage Intensity (million bbl/well completion) 0.16 0.22 0.21 Recycled (million bbl) 2.80 4.67 11.75 Sourced (million bbl) 22.60 46.65 55.75 Reportable Spill Events Released to the Environment (events) 178 159 212 Reportable Spill Volumes Released to the Environment (barrels) 3,247 4,101 3,978
GOVERNANCE METRICS 2016 2017 2018
Independent Board Members 78% 78% 80% Women Board Members 22% 22% 20% Political Contributions (thousands) $0.00 $1,062 $494 Lobbying - Federal & State (thousands) $0.00 $1,542 $905
SOCIAL METRICS 2016 2017 2018
Social Investments (thousands) $4,778 $6,692 $7,043
WORKFORCE METRICS 2016 2017 2018
Headcount (total company) 3,545 3,414 2,880 Minorities as a Percentage of Workforce (U.S. only)(3) 17% 17% 18% Women as a Percentage of Workforce 27% 27% 25% Median Age 38 39 40
(1) Our emissions reporting methodology varies depending on the emissions source and the applicable regulatory requirements. We include all reportable emissions under EPA's Greenhouse Gas Reporting Program (GHGRP), as well as non-reportable emissions, from
(2) Our U.S. methane emissions intensity rate calculation includes all natural gas produced at Devon operated facilities and all methane emissions from Devon facilities associated with the production of oil and natural gas. (3) As defined by the U.S. Equal Employment Opportunity Commission.
For additional information see our 2019 Sustainability Report