2Q20 EARNINGS PRESENTATION
August 2020
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.
2Q20 EARNINGS PRESENTATION
August 2020
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
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.
3 CIMAREX ENERGY: PILLARS OF SUCCESSFUL STRATEGY
Cimarex Energy: Pillars of Successful Strategy
PLANNING EXPLORATION ENVIRONMENT COST CONTROL DIGITAL INNOVATION
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)
5 ADJUSTING TO THE CHANGING ENVIRONMENT
Adjusting to the Changing Environment
EMPLOYEE HEALTH & SAFETY
pandemic
home
phased return to office
RESPONSE
line in June
completions in September
OIL PRICES HAVE IMPROVED, HEADWINDS REMAIN
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
NET WELLS ON PRODUCTION
12.5
$ MILLION 1QA 2QA
YTD
UPDATED 2020E GUIDANCE DRILLING & COMPLETION (D&C)1 $ 214 $ 49 $ 263 $ ~ 430 MIDSTREAM/SWD 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
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
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
10 DELAWARE BASIN ACREAGE
Delaware Basin Acreage
NEW MEXICO TEXAS
FEDERAL ACREAGE
238,000 NET ACRES WITH THREE MAJOR PLAYS
DEVELOPMENT PLANS INCLUDE ~5,000 FEDERAL ACRES 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
*
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:
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
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
COUNTY
*Includes XEC wells
13 CULBERSON: WATER INFRASTRUCTURE DRIVING EFFICIENCIES
Culberson: Water Infrastructure Driving Efficiencies
SALTWATER DISPOSAL (SWD)
development
WATER REUSE DRIVES EFFICIENCY
water in 2019
ENVIRONMENTAL BENEFITS
prevent spills
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
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
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
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
into 4Q20, before modest growth in December
meaningful 1H21 oil growth
2021-2024 2021
ASSUMING SIMILAR CAPITAL YEAR-OVER-YEAR:
at $35 WTI2
year-over-year
determined TARGETS INCLUDE:
at $35 WTI2, while maintaining flat to single digit production growth
in 2024
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
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
19 APPENDIX
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%
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 FERC2020 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 Weighted Average Price
(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
22 PERMIAN BASIN TAKEAWAY
Permian Basin Takeaway
OIL TRANSPORT AND SALES AGREEMENTS IN PLACE
strong flow assurance
GAS SALES AGREEMENTS IN PLACE
Project; 10 year firm commitment, provides access to Gulf Coast pricing, expected online 3Q21 OWN AND OPERATE TWO GAS GATHERING SYSTEMS
intrastate outlets
CIMAREX ACREAGE ENERGY TRANSFER PIPELINE EAGLECLAW OFFLOADING SITE PLAINS PIPELINE
23 PERMIAN BASIN WATER MANAGEMENT
Permian Basin Water Management
OWN AND OPERATE SALT WATER DISPOSAL (SWD) SYSTEMS IN CULBERSON, EDDY AND REEVES
RECYCLING PRODUCED WATER FOR COMPLETION OPERATIONS
IN 2019 – CULBERSON WOLFCAMP WELLS USED 94% RECYCLED WATER FOR COMPLETIONS; REEVES WOLFCAMP WELLS USED 25% SECURED SWD AGREEMENTS IN LEA COUNTY
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
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 abilityto 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.