2Q20 EARNINGS PRESENTATION August 2020 Forward-looking Statements - - PowerPoint PPT Presentation

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2Q20 EARNINGS PRESENTATION August 2020 Forward-looking Statements - - PowerPoint PPT Presentation

2Q20 EARNINGS PRESENTATION August 2020 Forward-looking Statements This presentation contains projections and other forward-looking statements within the meaning of Section 27A of the U.S. Securities Act of 1933 and Section 21E of the U.S.


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SLIDE 1

2Q20 EARNINGS PRESENTATION

August 2020

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SLIDE 2

2 FORWARD-LOOKING STATEMENTS

Forward-looking Statements

Contact: Karen Acierno Vice President – Investor Relations 303-285-4957 kacierno@cimarex.com

This presentation contains projections and other forward-looking statements within the meaning of Section 27A of the U.S. Securities Act of 1933 and Section 21E of the U.S. Securities Exchange Act of 1934. These projections and statements reflect the Company’s current views with respect to future events and financial performance. No assurances can be given, however, that these events will occur or that these projections will be achieved, and actual results could differ materially from those projected as a result of certain factors. A discussion of these factors is included in the Company’s periodic reports filed with the U.S. Securities and Exchange Commission. Actual results may differ materially from company projections and other forward-looking statements and can be affected by a variety of factors outside the control of the company including among other things: oil, NGL and natural gas price levels and volatility, including those resulting from demand destruction from the COVID-19 pandemic; disruptions to the availability of workers and contractors due to illness and stay at home orders related to the COVID-19 pandemic; disruptions to gathering, pipeline, refining, transportation and other midstream and downstream activities due to the COVID-19 pandemic; disruptions to supply chains and availability of critical equipment and supplies, including as a result of the COVID-19 pandemic; the effectiveness of controls over financial reporting; declines in the values of our oil and gas properties resulting in impairments; impairments of goodwill; higher than expected costs and expenses, including the availability and cost of services and materials, which may be negatively impacted by the COVID-19 pandemic; our ability to successfully integrate the March 2019 acquisition of Resolute Energy Corporation; compliance with environmental and other regulations; costs and availability of third party facilities for gathering, processing, refining and transportation; risks associated with concentration of operations in one major geographic area; environmental liabilities; the ability to receive drilling and other permits and rights-of-way in a timely manner, which may be negatively impacted by COVID-19 restrictions on regulatory personnel who process and approve those matters; development drilling and testing results; the potential for production decline rates to be greater than expected; performance of acquired properties and newly drilled wells; regulatory approvals, including regulatory restrictions on federal lands which may be negatively impacted by a change in administration; legislative or regulatory changes, including initiatives related to hydraulic fracturing, emissions and disposal of produced water, which may be negatively impacted by a change in administration; unexpected future capital expenditures; economic and competitive conditions; the availability and cost of capital; the ability to obtain industry partners to jointly explore certain prospects, and the willingness and ability of those partners to meet capital obligations when requested; changes in estimates of proved reserves; derivative and hedging activities; the success of the company's risk management activities; title to properties; litigation; the ability to complete property sales or

  • ther transactions; and other factors discussed in the company's reports filed with the SEC. Cimarex Energy Co. encourages readers to consider the risks and uncertainties associated with

projections and other forward-looking statements. In addition, the company assumes no obligation to publicly revise or update any forward-looking statements based on future events or circumstances.

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SLIDE 3

3 CIMAREX ENERGY: PILLARS OF SUCCESSFUL STRATEGY

Cimarex Energy: Pillars of Successful Strategy

PLANNING EXPLORATION ENVIRONMENT COST CONTROL DIGITAL INNOVATION

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SLIDE 4

4 OPERATIONAL HIGHLIGHTS

Operational Highlights

FLARING UPDATE

GENERATED CASH FROM OPERATING ACTIVITIES OF $145MM $26MM OF FREE CASH FLOW AFTER DIVIDEND OIL PRODUCTION OF 78.0 MBBLS/D TOTAL PRODUCTION OF 254.7 MBOE/D 12 NET WELLS BROUGHT ON PRODUCTION IN 2Q, 11 IN THE PERMIAN BASIN GO FORWARD AVERAGE PERMIAN WELL COSTS OF $800–900 PER FOOT

8.08 7.89 6.92

$6.00 $7.00 $8.00 $9.00 2Q19A 3Q19A 4Q19A 1Q20A 2Q20A

TOTAL COMPANY CASH OPERATING COSTS DOWN 14% FROM 2Q19 AND DOWN 12% SEQUENTIALLY

Cash operating costs include: LOE, Workover, Transportation, Production Tax, G&A

PER BOE

2020 PERMIAN FLARING INTENSITY TARGET: 1.44% STRETCH: 0.96% YTD: 1.08%

2Q UPDATES

Flaring Intensity = Flared Gas Volumes (Mcf)/Gross Permian Gas Production (Mcf)

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SLIDE 5

5 ADJUSTING TO THE CHANGING ENVIRONMENT

Adjusting to the Changing Environment

EMPLOYEE HEALTH & SAFETY

  • Multi-disciplinary approach to COVID-19

pandemic

  • COVID-19 Task Force
  • Return to Office Task Force
  • Field protocols in place
  • 50% of office staff continue to work from

home

  • Following CDC guidelines to implement

phased return to office

RESPONSE

  • Focused on Free Cash Flow
  • Reduced capital investment
  • Curtailed May production; brought back on

line in June

  • Measured return to activity
  • Adding three rigs in 3Q and restarting

completions in September

  • Improved efficiencies
  • Lower well costs and LOE

OIL PRICES HAVE IMPROVED, HEADWINDS REMAIN

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SLIDE 6

6 RESUMING ACTIVITY IN 3Q

Resuming Activity in 3Q

ADDING ONE DRILLING RIG PER MONTH AND TWO COMPLETION CREWS IN SEPTEMBER

Jul Aug Sep

20 10 46

1Q20A 2Q20A 3Q20E 4Q20E IN PROGRESS AT 12/31/20

NET WELL COUNT

PERMIAN BASIN ANADARKO BASIN

BROUGHT 12.5 NET WELLS ON PRODUCTION IN 2Q EXPECT TO BRING 43 NET WELLS ON PRODUCTION IN 2020

  • 46 wells in progress at year end 2020

NET WELLS ON PRODUCTION

12.5

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SLIDE 7

$ MILLION 1QA 2QA

YTD

UPDATED 2020E GUIDANCE DRILLING & COMPLETION (D&C)1 $ 214 $ 49 $ 263 $ ~ 430 MIDSTREAM/SWD 27

  • 27

~ 40 OTHER2 33 35 68 ~ 130 TOTAL CAPITAL INVESTMENT $ 274 $ 84 $ 358 $ ~ 600

7 CAPITAL INVESTMENT UPDATE

Capital Investment Update

1 Includes well facilities, flow back and outside operated wells 2 Capitalized overhead, production capital, land and technology

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SLIDE 8

Updated 2020 Delaware Basin Plans

2,000 4,000 6,000 8,000 10,000 CULBERSON EDDY REEVES LEA

8 UPDATED 2020 DELAWARE BASIN PLANS

REEVES CULBERSON LEA EDDY

WELLS ON LINE BY COUNTY 40 NET WELLS

WOLFCAMP BONE SPRING

$415 MM D&C CAPITAL AVERAGE LATERAL LENGTH BY COUNTY

BASIN AVERAGE: 9,000

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SLIDE 9

2020 DEVELOPMENTS ON LINE

PROJECT NAME WELLS % WI ON LINE 1 ELECTRIC STATE 5 100 1Q 2 CARRY BACK 2 80 1Q 3 RIVERBEND 5 86 1Q 4 VACA DRAW 6 50 1Q 5 GOAT 7 96 2Q 6 HIS EMINENCE 5 50 2Q 7 DIXIELAND 7 97 4Q20E

DEVELOPMENTS IN PROGRESS 12/31/20

8 RED HILLS 6 57 1Q21E 9 CRAWFORD 4 100 1Q21E 10 BIG SKY STATE 6 100 1Q21E 11 BURGOO KING 7 50 2Q21E 12 TIM TAM 6 50 2Q21E 13 NORTH TABLE 4 100 2Q21E 14 COUNT FLEET 7 50 2Q21E 15 DOS EQUIS 4 59 2Q21E 16 CAPPLETON 7 93 3Q21E 17 SNOWSHOE 5 100 3Q21E 18 SPECTACULAR BID 8 50 3Q21E 19 TAR HEEL 8 100 4Q21E 9 DELAWARE BASIN 2020 – DEVELOPMENT UPDATE

Delaware Basin 2020 – Development Update

3 4 2 5 6 1

NEW MEXICO TEXAS

CURRENTLY OPERATING THREE DRILLINGS RIGS

12 9 8 11 7 14

CIMAREX ACREAGE WOLFCAMP BONE SPRING AVALON FEDERAL ACREAGE

16 19 13 17 10 15 18

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SLIDE 10

10 DELAWARE BASIN ACREAGE

Delaware Basin Acreage

NEW MEXICO TEXAS

FEDERAL ACREAGE

238,000 NET ACRES WITH THREE MAJOR PLAYS

  • 33% federal acreage, all in New Mexico

DEVELOPMENT PLANS INCLUDE ~5,000 FEDERAL ACRES THROUGH 2023

  • 46 wells planned through 2023

~28% OF 2020 D&C CAPITAL INVESTMENT ON FEDERAL ACREAGE

CIMAREX ACREAGE WOLFCAMP BONE SPRING AVALON FEDERAL ACREAGE

FEDERAL PERMITS FOR WELLS ON RIG SCHEDULE PERMIT STATUS THROUGH 2023 APPROVED 32 IN PROGRESS 14

*Includes 16 wells which require extension before spud date

*

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SLIDE 11

11 PERMIAN REGION WELL COST IMPROVEMENTS

Permian Region Well Cost Improvements

WELL COST PER COMPLETED LATERAL FOOT (OPERATED) $1,479 $1,106

$- $200 $400 $600 $800 $1,000 $1,200 $1,400 $1,600 2018A 2019A 2020E

$/COMPLETED LATERAL FEET

$900 – 1,000

515,000 FEET 708,000 FEET 426,000 FEET

67 NET WELLS COMPLETED 76 NET WELLS COMPLETED 49 NET WELLS1

LATERAL FEET COMPLETED TOTAL CAPITAL ASSOCIATED WITH COMPLETED WELLS2

=

WELL COST PER LATERAL FOOT

2020 WELL COSTS TRENDING BELOW EXPECTATIONS GO FORWARD WELL COSTS:

  • Culberson: $750-800 per foot
  • Reeves: $800-850 per foot
  • Lea: $900-1,000 per foot

PERMIAN PROGRAM AVERAGE OF $800-900 PER FOOT

1Wells completed, but not necessarily on line in 2020 2Total capital includes D&C, facilities and flow back associated with wells completed in the period

$ PER COMPLETED LATERAL FOOT

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SLIDE 12

55 WELLS 81 271 231 256 86 507 34 51 199 187 185 63 396 22 43 128 147 122 44 300 17 23 77 95 69 38 196 50 100 150 200 250 300 350 400 450 XEC CULBERSON OTHER CULBERSON LEA* LOVING* EDDY* WARD* REEVES*

6 MONTHS 12 MONTHS 18 MONTHS 24 MONTHS

12 CULBERSON: TOP-TIER OIL WELLS

Culberson: Top-Tier Oil Wells

DELAWARE BASIN CUMULATIVE OIL PRODUCTION BY COUNTY

(>8,500 LL, First Prod >2016, Upper Wolfcamp & Bone Spring Formations)

CUMULATIVE OIL (MBBLS)

ATTRIBUTES OF CULBERSON COUNTY LONG LATERALS

  • Competitive Oil Production
  • Shallow Declines
  • Low Operating Costs (LOE)

COUNTY

*Includes XEC wells

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SLIDE 13

13 CULBERSON: WATER INFRASTRUCTURE DRIVING EFFICIENCIES

Culberson: Water Infrastructure Driving Efficiencies

SALTWATER DISPOSAL (SWD)

  • Own & operate the system
  • Improves operating costs
  • System redundancy reduces downtime
  • System expanding efficiently with additional

development

WATER REUSE DRIVES EFFICIENCY

  • On-demand recycled water lowers cost
  • Wolfcamp completions used 94% recycled

water in 2019

  • Saved $1.78/bbl for procured water

ENVIRONMENTAL BENEFITS

  • Avoids surface storage of produced water
  • Permanent underground flow helps to

prevent spills

  • Reduces need for fresh water

RISER: XEC-ENGINEERED ACCESS FOR WATER REUSE

XEC ACREAGE INFRASTRUCTURE OPERATED SWD

SWD INFRASTRUCTURE WOLFCAMP FRAC WATER

32% 87% 97% 94% 100% 2016 2017 2018 2019 1H20 RECYCLED PURCHASED

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SLIDE 14

14 MID-CONTINENT

Mid-Continent

326,000 NET ACRES WOODFORD: 135,625 NET UNDEVELOPED ACRES (HBP) MERAMEC: 116,500 NET ACRES (>98% HBP) FOCUSING ON HIGH QUALITY INVENTORY SUBSET, LOWERING COSTS AND A RISING COMMODITY ENVIRONMENT TRANSLATES INTO STRONG ECONOMICS

OKLAHOMA

CIMAREX ACREAGE MERAMEC OUTLINE WOODFORD OUTLINE

LONE ROCK 13-8 AREA

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SLIDE 15

15 LONG-TERM STRATEGY, NEAR-TERM PRIORITIES

Long-Term Strategy, Near-Term Priorities

Return on and of capital Capital discipline and asset optimization Focused execution

STRATEGY PRIORITIES

Employee health and safety Free cash flow generation and balance sheet strength Returning capital to shareholders through our dividend Financial strength

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SLIDE 16

16 FREE CASH FLOW OUTLOOK STRONG

Free Cash Flow Outlook Strong

1Assuming current strip prices for the balance of the year 2$35 WTI, $2.50 Henry Hub, 45% NGL of WTI

2020

PROJECTING $150-200MM1 OF FCF AFTER THE DIVIDEND

  • Production expected to decline

into 4Q20, before modest growth in December

  • 2H20 activity ramp will drive

meaningful 1H21 oil growth

2021-2024 2021

ASSUMING SIMILAR CAPITAL YEAR-OVER-YEAR:

  • Excess FCF after the dividend

at $35 WTI2

  • Oil volumes flat to slightly up

year-over-year

  • Dividend increase a priority
  • Strengthen balance sheet
  • 2021 capital plans to be

determined TARGETS INCLUDE:

  • Excess FCF after the dividend

at $35 WTI2, while maintaining flat to single digit production growth

  • Annual dividend increase
  • Generate FCF to retire notes

in 2024

  • Debt/EBITDA <1.0x
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SLIDE 17

17 STRONG BALANCE SHEET, CONSERVATIVE FINANCIAL POSITION

Strong Balance Sheet, Conservative Financial Position

INVESTMENT GRADE RATED NO NEAR-TERM DEBT MATURITIES $1.3 BILLION OF LIQUIDITY, INCLUDING $44 MILLION OF CASH (6/30/2020) EXPECT NO ADDITIONAL BORROWINGS IN 2020 AMPLE LIQUIDITY, NO NEAR-TERM DEBT MATURITIES

CASH CREDIT FACILITY DEBT

XEC DEBT/TTM EBITDA

$0 $200 $400 $600 $800 $1,000 $1,200 $1,400

LIQUIDITY 6/30/20 2024 2027 2029

$ MILLIONS DEBT MATURITIES 0.0x 0.5x 1.0x 1.5x 2.0x 2017A 2018A 2019A 1Q20A 2Q20A

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SLIDE 18

CREATING VALUE AND GENERATING TOP-TIER RETURNS

PROVEN TRACK RECORD

18 CIMAREX ENERGY OVERVIEW

Cimarex Energy Overview

PREMIER PORTFOLIO

CORE POSITIONS IN THE PERMIAN AND ANADARKO BASINS

ENDURING CULTURE

MAXIMIZING FULL- CYCLE RETURN ON INVESTED CAPITAL

STRONG FINANCIAL POSITION

LIQUIDITY PROVIDES FLEXIBILITY

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SLIDE 19

19 APPENDIX

APPENDIX

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20 RESUMING 2020 GUIDANCE

Resuming 2020 Guidance

3Q20E 2020E Production (MBOE/d) 230 – 250 240 – 250 Oil Production (MBbls/d) 69 – 74 75 – 78 Capital Expenditures ($ Million) D&C ~ $430 Midstream & Saltwater Disposal (SWD) ~ 40 Other ~ 130 Total Capital ~ $600 Expenses ($/BOE) Production $2.90 – 3.30 Transportation, processing & other $2.10 – 2.40 DD&A and ARO accretion $7.40 – 7.90 General and administrative $0.95 – 1.15 Taxes other than income (% of oil and gas revenue) 6.0% – 8.0%

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SLIDE 21

21 HEDGES AS OF AUGUST 5, 2020

Hedges as of August 5, 2020

Notes:

1 WTI refers to West Texas Intermediate oil prices as quoted on the New York Mercantile Exchange 2 Index price on basis swaps is WTI Midland as quoted by Argus Americas Crude 3 Index price on basis swaps is WTI NYMEX less weighted average differential shown in table 4 PEPL refers to Panhandle Eastern Pipe Line Tex/OK Mid-Continent as quoted on Platt’s Inside FERC 5 El Paso Perm refers to El Paso Permian Basin index as quoted on Platt’s Inside FERC 6 Waha refers to West Texas Natural Gas Index (“Waha”) as quoted in Platt’s Inside FERC

2020 2021 2022

OIL

3Q 4Q 1Q 2Q 3Q 4Q 1Q

WTI OIL COLLARS1 Volume (Bbl/d) 41,000 41,000 40,000 30,000 21,000 21,000 7,000 Weighted Average Floor 40.91 40.91 38.06 34.23 31.48 31.48 35.00 Weighted Average Ceiling 49.84 49.84 46.45 42.25 39.67 39.67 45.28 WTI OIL BASIS SWAPS2 Volume (Bbl/d) 32,000 32,000 31,000 25,000 20,000 20,000 7,000 Weighted Average Differential3 0.18 0.18 0.03 (0.10) (0.38) (0.38) 0.11 WTI OIL ROLL DIFFERENTIAL SWAPS1 Volume (Bbl/d)

  • 7,000

7,000 7,000 7,000 7,000 Weighted Average Price

  • (0.24)

(0.24) (0.24) (0.24) (0.24)

GAS

3Q 4Q 1Q 2Q 3Q 4Q 1Q

PEPL GAS COLLARS4 Volume (MMBtu/d) 100,000 100,000 100,000 90,000 70,000 70,000 40,000 Weighted Average Floor 1.78 1.78 1.83 1.83 1.88 1.88 2.00 Weighted Average Ceiling 2.21 2.21 2.23 2.22 2.29 2.29 2.40 EL PASO PERM GAS COLLARS5 Volume (MMBtu/d) 70,000 70,000 70,000 70,000 50,000 50,000 20,000 Weighted Average Floor 1.36 1.36 1.50 1.50 1.64 1.64 1.85 Weighted Average Ceiling 1.64 1.64 1.79 1.79 1.95 1.95 2.18 WAHA GAS COLLARS6 Volume (MMBtu/d) 70,000 70,000 90,000 90,000 70,000 70,000 40,000 Weighted Average Floor 1.43 1.43 1.52 1.52 1.65 1.65 1.77 Weighted Average Ceiling 1.73 1.73 1.83 1.83 1.98 1.98 2.15

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SLIDE 22

22 PERMIAN BASIN TAKEAWAY

Permian Basin Takeaway

OIL TRANSPORT AND SALES AGREEMENTS IN PLACE

  • ~89% of oil production on pipe
  • Strategic partnerships in core producing areas provide

strong flow assurance

  • Oil sales arrangements with credit worthy counterparties

GAS SALES AGREEMENTS IN PLACE

  • 97% of remaining 2020 production has been sold forward
  • Local pricing
  • Committed 125,000 MMBtu per day to Whistler Pipeline

Project; 10 year firm commitment, provides access to Gulf Coast pricing, expected online 3Q21 OWN AND OPERATE TWO GAS GATHERING SYSTEMS

  • Triple Crown – Culberson/Eddy Counties
  • Matterhorn – Reeves County
  • Connected to multiple gas processors with inter- and

intrastate outlets

  • Long-term sales agreements in place for NGL volumes

CIMAREX ACREAGE ENERGY TRANSFER PIPELINE EAGLECLAW OFFLOADING SITE PLAINS PIPELINE

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SLIDE 23

23 PERMIAN BASIN WATER MANAGEMENT

Permian Basin Water Management

OWN AND OPERATE SALT WATER DISPOSAL (SWD) SYSTEMS IN CULBERSON, EDDY AND REEVES

  • Improves operating costs

RECYCLING PRODUCED WATER FOR COMPLETION OPERATIONS

  • 63% of total water procured in 2019 was recycled
  • Cost savings of ~$0.65/bbl of water

IN 2019 – CULBERSON WOLFCAMP WELLS USED 94% RECYCLED WATER FOR COMPLETIONS; REEVES WOLFCAMP WELLS USED 25% SECURED SWD AGREEMENTS IN LEA COUNTY

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SLIDE 24

24 NON-GAAP RECONCILIATION

Non-GAAP Reconciliation

($ MILLIONS) 2017 2018 2019 LTM 6/30/20 Net income (loss) $ 494 $ 792 $ (125) $ (1,960) Income tax expense (benefit) 188 231 (26) (357) Interest expense, net of capitalized 52 47 37 38 DD&A and ARO accretion 462 598 891 899 EBITDA 1,196 1,668 777 (1,380) Impairment of oil and gas — — 619 1,894 Impairment of goodwill — — — 714 ADJUSTED EBITDA1 1,196 1,668 1,396 1,228

1The above table provides a reconciliation from generally accepted accounting principles (GAAP) net income

(loss) to non-GAAP EBITDA and non-GAAP adjusted EBITDA, which excludes ceiling test impairments

THREE MONTHS ENDED JUNE 30, ($ MILLIONS) 2020 2019 Net cash provided by operating activities $ 145 $ 414 Change in operating assets and liabilities

  • (78)

Adjusted cash flow from operations2 145 336 Oil and gas expenditures (153) (379) Other capital expenditures (12) (22) Change in capital accruals 69 61 Free cash flow 49 (4) Dividends paid (24) (21) Free cash flow after dividend $ 26 $ (25) TWELVE MONTHS ENDED DECEMBER 31, LTM ($ MILLIONS) 2017 2018 2019 6/30/20 Long-term debt (principal) $1,500 $1,500 $2,000 $2,000 Adjusted EBITDA 1,196 1,668 1,396 1,228 Debt/Adjusted EBITDA 1.3x 0.9x 1.4x 1.6x 2019 ADDITIONS TO PROVED RESERVES (MMBOE) Revisions of previous estimates (50.7) Extensions & discoveries 119.3 Purchase of reserves 63.0 TOTAL ADDITIONS (ALL SOURCES) 131.6

2Management uses the non-GAAP financial measures of adjusted cash flow from operations, free cash flow and free cash flow after dividend as means of measuring our ability

to fund our capital program and dividends, without fluctuations caused by changes in current assets and liabilities, which are included in the GAAP measure of net cash provided by operating activities. Management believes these non-GAAP financial measures provide useful information to investors for the same reason, and that they are also used by professional research analysts in providing investment recommendations pertaining to companies in the oil and gas exploration and production industry.