THIRD QUARTER 2018 EARNINGS REVIEW Todd Stevens | President & CEO | November 1, 2018 Mark Smith | Senior EVP & CFO
Forward Looking / Cautionary Statements – Certain Terms This presentation contains forward-looking statements that involve risks and uncertainties that could materially affect our expected results of operations, liquidity, cash flows and business prospects. Such statements include those regarding our expectations as to our future: • financial position, liquidity, cash flows and results of operations • operations and operational results including production, hedging and capital investment • business prospects • budgets and maintenance capital requirements • transactions and projects • reserves • operating costs • type curves • Value Creation Index (VCI) metrics, which are based on certain estimates including • expected synergies from acquisitions and joint ventures future production rates, costs and commodity prices Actual results may differ from anticipated results, sometimes materially, and reported results should not be considered an indication of future performance. While we believe assumptions or bases underlying our expectations are reasonable and make them in good faith, they almost always vary from actual results, sometimes materially. We also believe third-party statements we cite are accurate but have not independently verified them and do not warrant their accuracy or completeness. Factors (but not necessarily all the factors) that could cause results to differ include: • commodity price changes • changes in business strategy • debt limitations on our financial flexibility • PSC effects on production and unit production costs • insufficient cash flow to fund planned investments, debt repurchases or changes to our • effect of stock price on costs associated with incentive compensation capital plan • insufficient capital, including as a result of lender restrictions, unavailability of capital • inability to enter desirable transactions, including acquisitions, asset sales and joint markets or inability to attract potential investors ventures • effects of hedging transactions • legislative or regulatory changes, including those related to drilling, completion, well • equipment, service or labor price inflation or unavailability stimulation, operation, maintenance or abandonment of wells or facilities, managing • availability or timing of, or conditions imposed on, permits and approvals energy, water, land, greenhouse gases or other emissions, protection of health, safety • lower-than-expected production, reserves or resources from development projects, joint and the environment, or transportation, marketing and sale of our products ventures or acquisitions, or higher-than-expected decline rates • joint ventures and acquisitions and our ability to achieve expected synergies • disruptions due to accidents, mechanical failures, transportation or storage constraints, • the recoverability of resources and unexpected geologic conditions natural disasters, labor difficulties, cyber attacks or other catastrophic events • incorrect estimates of reserves and related future cash flows and the inability to replace • factors discussed in “Risk Factors” in our Annual Report on Form 10 -K available on our reserves website at crc.com. Words such as "anticipate," "believe," "continue," "could," "estimate," "expect," "goal," "intend," "likely," "may," "might," "plan," "potential," "project," "seek," "should," "target, "will" or "would" and similar words that reflect the prospective nature of events or outcomes typically identify forward-looking statements. Any forward-looking statement speaks only as of the date on which such statement is made and we undertake no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law. See the Investor Relations page at www.crc.com for important information about 3P reserves and other hydrocarbon resource quantities, organic finding and development (F&D) costs, organic recycle ratio calculations, original hydrocarbons in place, Value Creation Index (VCI), drilling locations and reconciliations of non-GAAP measures to the closest GAAP equivalent. 3Q 2018 Earnings | 2
Key Highlights 3 rd Quarter 2018 3QYTD 2018 95 Gross Wells 252 Gross Wells Drilled 1 Drilled 1 ACTIVITY includes 59 CRC wells includes 151 CRC wells 136 Mboe/d 131 Mboe/d PRODUCTION 62% Oil 62% Oil $196 Million 2 $550 Million 2 $158 million internally funded $467 million internally funded Capital $308 Million $803 Million $400 million Core $1,022 million Core Adjusted EBITDAX 3 Adj. EBITDAX 3 Adjusted EBITDAX 3 1 Includes JV and non-operated wells. 2 Includes JV capital. 3 Core Adjusted EBITDAX excludes the effect of settled hedges of $79 million in the third quarter and $178 million in the first nine months, and cash-settled equity compensation of $13 million in the third quarter and $41 million in the first nine months. See the Investor Relations page at www.crc.com for historical reconciliations to the closest GAAP measure and other important information. 3Q 2018 Earnings | 3
CRC’s Value -Driven Strategic Approach Capture Value of Ensure Effective Drive Operational Strengthen Portfolio Capital Allocation Excellence Balance Sheet • Pursue value-driven • Utilize VCI-based • Streamline processes • Reinvest to grow cash production decision-making flow • Apply technology • Delineate future growth • Optimize core operating • Simplify capital areas area investment • Leverage sizeable structure infrastructure • Enhance already • Enhance targeted • Enhance credit metrics substantial inventory growth area investment • Drive strategic consolidation • Pursue value-accretive • Pursue strategic joint • Pursue impactful M&A ventures capital workovers • Employ new thinking and approaches • Reduce absolute level of debt Proven and pressure-tested strategic approach preserved value through the downturn and is set to drive significant value creation for years to come 3Q 2018 Earnings | 4
Development Results Driving Growth Drilling Prog rogram m His istory Q3 2018 Opera eration tions s Re Resul sults ts 125 San Joaquin Los Angeles Ventura Sacramento 100 Wells Drilled Sacramen ento to Basin in 75 5,000 BOE per Day No Drilling Rigs in Q3 50 25 0 1Q17 2Q17 3Q17 4Q17 1Q18 2Q18 3Q18 San Joaquin quin Basin in 99,000 BOE per Day YTD 2018 Re Resul sults ts of Majo jor r Drilling Prog rograms ms 7 Drilling Rigs Well Count Avg 30 Day IP 250 50 Avg 30 Day IP (BOEPD) Wells Online >30 days 200 40 Ventu tura Basi sin 150 30 6,000 BOE per Day 100 20 No Drilling Rigs in Q3 50 10 Los os Angel eles es Basin in 0 0 26,000 BOE per Day Huntington Long Beach BV Hills BV Nose (Pre-Steam) 1 1,2 3 Drilling Rigs Beach Kern Front Avg D&C $3.6 MM $1.6 MM $2.3 MM $3.5 MM $0.4 MM Cost per well 3 1 Includes JV wells. 2 Kern Front wells are steam flood wells which have low IPs and then ramp up over a period of 12-24 months. Los Angeles Basin San Joaquin Basin 3 Year to date drilling costs may not be comparable to prior periods due to variances in project mix, well depth, horizontal length and other aspects. 3Q 2018 Earnings | 5
Unlocking Value with a Deep Inventory of Actionable Projects at $75 Brent 50 Steamflood 45 • Fully burdened , growth- Full Cycle Cost 1 ($/Boe) Waterflood 40 focused portfolio Primary 35 Shale 30 • Achieve a VCI of 1.3 or Gas 25 greater at $75 Brent and 20 $3.00 NYMEX 15 10 • Deliver robust cash flow 5 0 • Reflects all recovery 0 100 200 300 400 500 600 700 800 900 1,000 mechanisms and reserves Net Resources 2 (MMBoe) types 12 Dev Capital (B$) • Leverage existing 9 infrastructure, while 6 opportunistically targeting 3 new infrastructure investment 0 0 100 200 300 400 500 600 700 800 900 1,000 Net Resources 2 (MMBoe) 1 Full cycle costs = operating costs + development costs + facility costs + field-level G&A + taxes other than on income. 2 See the Investor Relations page at www.crc.com for details regarding net resources. 3Q 2018 Earnings | 6
Strategic Consolidation of Elk Hills Assets Estimated Annualized Elk Hills Synergies* ($MM) Initial Target $34MM Realized $0 $5 $10 $15 $20 $25 $30 $35 • CRC acquired Chevron’s non -operating working Existing CRC Surface Acreage interest ranging between 20% to 22% in different Acquired Surface Acreage producing horizons within the Elk Hills field for Elk Hills Unit total consideration of $460MM in cash and 2.85MM CRC shares of common stock , closed Elk Hills Unit early April using some of the Ares proceeds 47,000 • CRC now owns Elk Hills Unit in fee simple , acres holding 100% WI, NRI and surface lands • Over $15MM in additional capital cost avoidance • Acquired ~10,000 surface fee acres CRC now owns 100% WI & NRI in its largest field *Synergies include operational cost savings and revenue enhancement 3Q 2018 Earnings | 7
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