crc 1q 2019 earnings presentation · pdf file 1q 2019 earnings | 3 key highlights $301 million...

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  • First Quarter 2019 Earnings Review May 2, 2019

    Todd Stevens | President & CEO

    Mark Smith | Senior EVP & CFO

  • 1Q 2019 Earnings | 2

    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:

    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:

    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.

    • financial position, liquidity, cash flows and results of operations

    • business prospects

    • transactions and projects

    • operating costs

    • Value Creation Index (VCI) metrics, which are based on certain estimates including

    future production rates, costs and commodity prices

    • operations and operational results including production, hedging and capital investment

    • budgets and maintenance capital requirements

    • reserves

    • type curves

    • expected synergies from acquisitions and joint ventures

    • commodity price changes

    • debt limitations on our financial flexibility

    • insufficient cash flow to fund planned investments, debt repurchases or changes to our

    capital plan

    • inability to enter desirable transactions, including acquisitions, asset sales and joint


    • legislative or regulatory changes, including those related to drilling, completion, well

    stimulation, operation, maintenance or abandonment of wells or facilities, managing

    energy, water, land, greenhouse gases or other emissions, protection of health, safety

    and the environment, or transportation, marketing and sale of our products

    • joint ventures and acquisitions and our ability to achieve expected synergies

    • the recoverability of resources and unexpected geologic conditions

    • incorrect estimates of reserves and related future cash flows and the inability to replace


    • changes in business strategy

    • PSC effects on production and unit production costs

    • effect of stock price on costs associated with incentive compensation

    • insufficient capital, including as a result of lender restrictions, unavailability of capital

    markets or inability to attract potential investors

    • effects of hedging transactions

    • equipment, service or labor price inflation or unavailability

    • availability or timing of, or conditions imposed on, permits and approvals

    • lower-than-expected production, reserves or resources from development projects, joint

    ventures or acquisitions, or higher-than-expected decline rates

    • disruptions due to accidents, mechanical failures, transportation or storage constraints,

    natural disasters, labor difficulties, cyber attacks or other catastrophic events

    • factors discussed in “Risk Factors” in our Annual Report on Form 10-K available on our

    website at

    Forward Looking / Cautionary Statements – Certain Terms

    See the Investor Relations page at for important information about 3P reserves and other hydrocarbon resource quantities, PV-10 and standardized measure, finding and development

    (F&D) costs, recycle ratio calculations, reserve replacement ratios, Value Creation Index (VCI), debt adjusted shares calculation, drilling locations and reconciliations of non-GAAP measures to the

    closest GAAP equivalent.

  • 1Q 2019 Earnings | 3

    Key Highlights

    $301 Million $1,168 million LTM

    1st Quarter 2019

    1 Includes all wells drilled by CRC, including JV wells. 2 Includes BSP and MIRA capital. 3 See the Investor Relations page at for

    historical reconciliations to the closest GAAP measure and other important information.

    4 Calculated as oil and gas revenue, including settled hedges, on a per BOE basis, less production costs per BOE, excluding the effect of PSC-type contracts.

    $138 Million2

    $104 million internally funded

    133 Mboe/d 63% Oil

    60 Total Wells Drilled1

    Includes 42 CRC wells

    Adj. EBITDAX3 Growth

    Operating Margin4 Growth

  • 1Q 2019 Earnings | 4


    Balance Sheet Drive Operational


    Ensure Effective

    Capital Allocation

    CRC’s Value-Driven Strategic Approach

    • Reinvest to grow cash


    • Simplify capital


    • Enhance credit metrics

    • Pursue value-accretive


    • Reduce absolute level of


    • Utilize VCI-based


    • Optimize core operating

    area investment

    • Enhance targeted

    growth area investment

    • Pursue impactful

    capital workovers

    • Streamline processes

    • Apply technology

    • Leverage sizeable


    • Drive strategic


    • Employ new thinking

    and approaches

    • Pursue value-driven

    production growth

    • Delineate future growth


    • Enhance already

    substantial inventory

    • Pursue strategic joint


    Capture Value

    of Portfolio

    Proven and pressure-tested strategic approach

    preserved value through the downturn and is set to

    drive significant value creation for years to come

  • 1Q 2019 Earnings | 5







    1Q17 2Q17 3Q17 4Q17 1Q18 2Q18 3Q18 4Q18 1Q19

    G ro

    s s W

    e ll s D

    ri ll e

    d San Joaquin Los Angeles Ventura

    Drilling Program History







    Huntington Beach

    Long Beach BV Hills BV Nose (Pre-Steam) Kern Front









    A v g 3

    0 D

    a y

    P e

    a k

    R a

    te (

    B O

    E P

    D )

    W e

    ll s O

    n li n

    e >

    3 0

    d a


    Well Count Avg 30 Day Peak Rate

    2 2,3

    Development Results Driving Growth

    Sacramento Basin

    5,000 BOE per day

    No Active Drilling

    San Joaquin Basin

    97,000 BOE per day

    6 Drilling Rigs1

    Ventura Basin

    6,000 BOE per day

    No Active Drilling

    Los Angeles Basin

    25,000 BOE per day

    1 Drilling Rig1

    Los Angeles Basin San Joaquin Basin

    1 Average CRC operated drilling rigs per quarter. 2Includes JV wells. 3 Kern Front wells are steam flood wells which have low IPs and then ramp up over a period of 12-24 months. 4 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.

    Avg D&C

    Cost per well4 $3.5 MM $1.7 MM $2.2 MM $3.9 MM $0.4 MM

    FY 2018 Results of Major Drilling Programs

    Q1 2019 Operations Results

  • 1Q 2019 Earnings | 6

    Unlocking Value with a Deep Inventory of Actionable Projects at $65 Brent

    • Fully burdened, growth-focused


    • Achieve a VCI of 1.3 or greater at

    $65 Brent and $3.00 NYMEX

    • Deliver robust cash flow

    • Reflects all recovery

    mechanisms and reserves types

    • Leverage existing infrastructure,

    while opportunistically targeting

    new infrastructure investment




    0 100 200 300 400 500 600 700 800D ev

    C ap

    it al

    ( B

    $ )

    Net Resources2 (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 for details

    regarding 3P resources and other hydrocarbon resource








    0 100 200 300 400 500 600 700 800

    Fu ll

    C yc

    le C

    o st

    1 ($

    /B o


    Net Resources2 (MMBoe)

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