39 th Annual Institutional Investors Conference Mark Smith | Senior - - PowerPoint PPT Presentation

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39 th Annual Institutional Investors Conference Mark Smith | Senior - - PowerPoint PPT Presentation

Raymond James & Associates 39 th Annual Institutional Investors Conference Mark Smith | Senior Executive Vice President & CFO | Orlando, FL | March 5, 2018 Forward Looking / Cautionary Statements This presentation contains forward-looking


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Mark Smith | Senior Executive Vice President & CFO | Orlando, FL | March 5, 2018

Raymond James & Associates

39th Annual Institutional Investors Conference

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Raymond James and Associates 39th Annual Institutional Investors Conference | 2

Forward Looking / Cautionary Statements

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. See www.crc.com Investor Relations for important information about 3P reserves and other hydrocarbon resource quantities, finding and development costs, recycle ratio calculations, and drilling locations.

  • financial position, liquidity, cash flows and results of operations
  • business prospects
  • transactions and projects
  • perating costs
  • Value Creation Index metrics (VCIs), which are based on certain estimates

including future production rates, costs and commodity prices

  • perations and operational results including production, hedging and capital

investment

  • budgets and maintenance capital requirements
  • reserves
  • type curves
  • commodity price changes
  • debt limitations on our financial flexibility
  • insufficient cash flow to fund planned investment
  • inability to enter desirable transactions including asset sales and joint

ventures

  • 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

  • ther emissions, protection of health, safety and the environment, or

transportation, marketing and sale of our products

  • unexpected geologic conditions
  • changes in business strategy
  • inability to replace reserves
  • insufficient capital, including as a result of lender restrictions, unavailability
  • f capital markets or inability to attract potential investors
  • inability to enter efficient hedges
  • 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 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 crc.com.

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Raymond James and Associates 39th Annual Institutional Investors Conference | 3 500 1,000 1,500 2,000 2,500

2017 2018E 2019E 2020E 2021E

$MM

Value Proposition – Multiple Ways to Increase Valuation

Disciplined Portfolio Management EBITDAX Growth* Positioned to Move from Defense to Offense

  • Increasing

Investments and Deploying Rigs

  • Joint Ventures
  • Opportunistic

Deleveraging

  • Operating Leverage to

Crude Oil

*See Slide 22 for additional information regarding EBITDAX Growth planning scenarios.

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Raymond James and Associates 39th Annual Institutional Investors Conference | 4

CRC’s Large Resource Base with Advantaged Infrastructure

Sacram amento ento Basin in 14 MMBOE Proved Reserves 6 MBOE/d production (100% dry gas) San Joaquin uin Basin in 419 MMBOE Proved Reserves 90 MBOE/d production (58% oil) Ventur ura a Basin in 40 MMBOE Proved Reserves 6 MBOE/d production (63% oil)

World rld-Class ss Resou

  • urce

ce Base

  • Operate 4 of the largest fields in the continental U.S.
  • Diversified, conventional portfolio with low base decline rate
  • 618 MMBOE proved reserves
  • 129 MBOE/d production, 64% oil
  • 2.3 million net mineral acres

Position itioned ed to Grow

  • w
  • Internally funded capital program designed to live within

cash flow and drive growth

  • Development investment augmented by JV capital and

increases flexibility

  • Operating flexibility across basins and drive mechanisms to
  • ptimize growth through commodity price cycles
  • Increasing crude oil mix improves margins
  • Deep inventory of high-return projects

Reserves as of 12/31/17; Production figures reflect average FY 2017 rates.

Los Angel eles Basin in 145 MMBOE Proved Reserves 27 MBOE/d production (100% oil)

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Raymond James and Associates 39th Annual Institutional Investors Conference | 5

Resilient Resource Base

25 50 75 100 125 150 175 200 20 40 60 80 100 120 140 160 180 1Q16 2Q16 3Q16 4Q16 1Q17 2Q17 3Q17 4Q17 FY 2015 FY 2016 FY 2017 Capita ital l ($MM) MBoe/d /d

)

Oil NGL Gas Total Capital Internally Funded Capital

Producti roduction

  • n By St

Strea eam m (Mboe/d) boe/d)

Note: Capital and production for 2017 include BSP’s investment and exclude MIRA’s investment.

Total Capital: $75MM $401MM $371MM* Internally Funded Capital: $275MM

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Raymond James and Associates 39th Annual Institutional Investors Conference | 6 Drilling 24% Workover 18% BSP JV Capital 22% MIRA JV Capital 14% Exploration 2% Other1 6% Development Facilities 14%

Moved ed from rom Defe fense se to Of Offen ense se – 2017 7 Revie view

  • CRC 2017 capital plan was directed to oil-weighted projects in our core fields: Elk Hills, Wilmington, Kern Front, Buena Vista, Mt. Poso, Pleito

Ranch, Wheeler Ridge and the delineation of Kettleman North Dome

  • JV capital was primarily focused in the San Joaquin Basin

2017 Capital Investment Program Summary

Total: $429 million3

1Other includes maintenance and occupational health, safety and environmental projects, seismic and other investments. 2Facility Costs and other non-return capital are apportioned to producing wells in the year they are drilled. 3Includes capital funded by MIRA, which is not included in our consolidated results.

2017 Total al Capital tal In Inve vest sted ed

1.70 2.00 30% 45% 0% 10% 20% 30% 40% 50% 0.00 0.50 1.00 1.50 2.00 2.50 $55 Brent Flat $3 NYMEX $55 Brent 2017, $65 Brent in 2018+ & $3 NYMEX

IRR VCI

VCI IRR

Results lts of Full lly-Burde urdened ed2 2017 CRC Deve velopm lopment ent Pro rogr gram am

Total: ~$240 million

Other1

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Raymond James and Associates 39th Annual Institutional Investors Conference | 7

Development Joint Ventures: A Force Multiplier

$154 Million

$260 MM Committed

~3.5-4.0 MBoe/d

Gross Peak Production per $100 MM of development capital

>12 MMBoe

Potential Targeted Reserves per $100 MM of development capital

JVs are generally focused in the San Joaquin Basin

$550 Million

Total Potential JV Capital

Kern Front

  • Legend-

Oxy Land Oil Fields Gas Fields

Buena Vista Pleito Ranch Elk Hills Kettleman North Dome Lost Hills Mt Poso

CRC Land

Portfolio Flexibility and Optionality Enables High Margin Production Growth Accelerate Value Derisk Inventory

JVs add production and cashflow, and help de-risk inventory to increase CRC’s reserve base

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Raymond James and Associates 39th Annual Institutional Investors Conference | 8

$100 $100 $193 $2,250 $1,000 $1,300 $0

$0 $500 $1,000 $1,500 $2,000 $2,500 $3,000 $3,500 $4,000 Sep-17 Dec-17 Mar-18 Jun-18 Sep-18 Dec-18 Mar-19 Jun-19 Sep-19 Dec-19 Mar-20 Jun-20 Sep-20 Dec-20 Mar-21 Jun-21 Sep-21 Dec-21 Mar-22 Jun-22 Sep-22 Dec-22 Mar-23 Jun-23 Sep-23 Dec-23 Mar-24 Jun-24 Sep-24 Dec-24 2014 RCF 2017 Term Loan 2016 Term Loan 2nd Lien Notes Unsecured Notes

Strengthening the Balance Sheet - Improved Creditworthiness and Liquidity

  • Pro forma net results from the Ares transactions which closed on February 7, 2018:
  • The RCF was paid in full
  • CRC received $797 million in net proceeds, $8mm of which is restricted cash
  • The RCF has approximately $850 million of available borrowing capacity, excluding

$150 million minimum liquidity

  • The recent amendment extends the maturity of the RCF to June 2021 and relaxes

financial covenants

1st Lien 2014 Revolving Credit Facility (RCF)

  • 1st Lien 2017 Term Loan

1,300 1st Lien 2016 Term Loan 1,000 2nd Lien Notes 2,250 Senior Unsecured Notes 393 Total Debt 4,943 Less cash2 (441) Total Net Debt 4,502 Equity3 (764) Total Net Capitalization 3,738 Total Net Debt / Total Net Capitalization 120% Total Net Debt / LTM Adjusted EBITDAX4 5.9x LTM Adjusted EBITDAX4 / LTM Interest Expense 2.2x PV-105 / Total Net Debt 1.0x Total Net Debt / Proved Reserves ($/Boe) $7.28 Total Net Debt / Proved Developed Reserves ($/Boe) $10.23 Total Net Debt / 2017 Production ($/Boepd) $34,899

Pro ro-Forma ma1 Capital talization zation ($MM) Pro ro-Forma1 Debt t Matur uriti ties es ($MM)* )*

1 Pro-forma capitalization table and debt maturities graph reflect the payoff of the 12/31/17 outstanding balance

  • f $363 million on our RCF after the completion of the Ares JV and $50 million private placement.

2 The $441 million of available cash includes (1) $15 million unrestricted cash as of 12/31/17 and (2) $426

million of available cash after the Ares transaction and proforma repayment of the RCF.

3 Excludes noncontrolling interest at 12/31/17 and includes $50 million of equity from the Ares private placement. 4 See www.crc.com, Investor Relations for a reconciliation to the closest GAAP measure and other important

information.

5 PV-10 as of 12/31/17, see Attachment 2 of CRC’s Fourth Quarter Earnings Release dated February 26, 2018 for

details on this calculation. * Previously, the RCF, the 2017 Term Loan and the 2016 Term Loan were subject to springing maturities related to the 2020 and 2021 Notes. During the fourth quarter of 2017, CRC repurchased $65 million in principal amount of the 2020 Notes and $35 million in principal amount of the 2021 Notes, which eliminated the springing maturity feature. The 2017 Term Loan also has a springing maturity related to the 2016 Term Loan.

Undrawn RCF

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Raymond James and Associates 39th Annual Institutional Investors Conference | 9

Value Additive Inventory Growth

  • Comprehensive technical review of 40% of CRC’s fields.
  • 2017 Proved reserves of 618 MMBOE and 450 million

BOE of probable reserves.

  • 119% organic reserve replacement, excluding the effect
  • f price adjustments.
  • We added 34 million BOE of proved reserves from

extension and discoveries and 22 million BOE from

  • performance. We were also able to rebook 49 million

BOE due to the increase in prices compared to prior years.

  • Organic F&D costs excluding price related revisions was

$6.82 per BOE and produced a recycle ratio of 2.1x.

  • Over 95% of our total proved reserves have been

audited by Ryder Scott in the last three years.

3P Rese serves s Gro rowth th

58 109 156 768 644 568 618 222 251 202 321 340 826 1,129 250 500 750 1,000 1,250 1,500 1,750 2,000 2,250 Spin-off 2015 2016 2017

MMBoe

Cummulative Production Proven Revisions Due to Price Since 2014 Unproven

>350% Growth

See www.crc.com Investor Relations for important information about 3P reserves and other hydrocarbon quantities.

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Raymond James and Associates 39th Annual Institutional Investors Conference | 10

Deep Inventory of Actionable Projects at $65

Portfolio Spectrum

  • Growth portfolio focus, fully

ly burde dened ed

  • All projects meet a Value

Creation Index (VCI)1 threshold of 1.3 at $65 Brent and $3.50 NYMEX, and deliver robust cash flow

  • Portfolio has large

contributions from all recovery mechanisms and reserves types

  • Many projects take

advantage of existing infrastructure, while other new projects may require infrastructure investment in facilities and sales points

1VCI is calculated by dividing the net present value of the project’s expected pre-tax cash flow over its life by the net present value of the investments, each using a 10% discount rate. 2Full cycle costs = operating costs + development costs + facility costs + field-level G&A + taxes other than on income. 3See www.crc.com, Investor Relations for details regarding net resources.

2 4 6 8 10 100 200 300 400 500 600 700 800 Development Capital ($B) Net Resources3 (MMBoe) 5 10 15 20 25 30 35 40 45 50 100 200 300 400 500 600 700 800 Full Cycle Cost2 ($/Boe) Net Resources3 (MMBoe)

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Raymond James and Associates 39th Annual Institutional Investors Conference | 11

PDP Value Proved Value Unproved4 $0 $4 $8 $12 $16 $20 $24

$55 Brent $65 Brent $75 Brent ($Billion)

2017 Reserves Value1 In Excess EV

Curren ent EV

  • f $6.4

.4 Bn5 Infrastructure2 Surface & Minerals3

1-5 See endnotes in the Appendix.

See www.crc.com Investor Relations for important information about 3P reserves and other hydrocarbon quantities.

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Raymond James and Associates 39th Annual Institutional Investors Conference | 12

Largest California Producer with Deep Regional Insight

Surface & Minerals3

177 154 129 33 26

  • 50

100 150 200

CRC Chevron USA Aera Energy Sentinel Peak Berry Gross Operated MBoe/d

*Source: DOGGR data (average production data for 2016), IHS, Wood Mackenzie, Company Estimates. * *For non-CRC Companies, estimated 2016 OPEX $/Boe.

Largest 3-D Seismic Position in California

$16 $23 $22 $29 $29

$0 $5 $10 $15 $20 $25 $30 $35 0% 25% 50% 75% 100% CRC Chevron USA Aera Energy Sentinel Peak Berry

OPEX $/Boe** Production Mix

Shallow Deeper (>5,000') FY 2016 OPEX $/BOE**

MONTEREY SANDS AND SHALES TEMBLOR SANDS EOCENE SANDS AND SHALES UPPER CRETACEOUS SANDS AND SHALES 1,000’ PAY TULARE SANDS SHALLOW DEEP ETCHEGOIN SANDS <5,000’ 15,000’

Top California Producers in 2016* Majority of CA Production is Shallow*

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Raymond James and Associates 39th Annual Institutional Investors Conference | 13

San Joaquin Basin – An American Super Basin

Ove Overvie view

  • Oil and gas discovered in the late 1800s
  • 70% of CRC production is from San Joaquin Basin
  • Cretaceous to Pleistocene sedimentary section (>25,000 feet)
  • Source rocks are organic rich shales from Moreno, Kreyenhagen, Tumey and

Monterey Formations

  • Thermal recovery applied since 1960s
  • Currently running 7 drilling rigs

Key y Asset sets

  • 2017 average net production of 90 MBOE/d (58% oil)
  • Elk Hills is the flagship asset (~59% of FY 2017 CRC San Joaquin production)
  • Two core steamfloods - Kern Front and Lost Hills
  • Early stage waterfloods at Buena Vista and Mount Poso

25 billion OOIP (BOE) in CRC fields

Basin in Map

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Raymond James and Associates 39th Annual Institutional Investors Conference | 14

Elk Hills Area – CRC’s Flagship Asset

Integr ntegrated d Inf nfrast rastru ructure cture

  • 610 MMcf/d processing capacity through 4 gas plants
  • Including California’s largest
  • 3 CO2 removal plants
  • Over 4,500 miles of gathering lines
  • 45 MW cogeneration plant
  • 550 MW power plant

1 DOGGR data and U.S. Energy Information Administration.

  • 5

10 15 20 20 40 60 80 100 120

1998 2000 2002 2004 2006 2008 2010 2012 2014 2016

Rig Count

Net MBOE/d

Net MBOEPD Rig Count

Ove Overvie view

  • CRC’s flagship, a 100 year-old field with exploration opportunities
  • Light oil from conventional and unconventional production
  • Largest gas and NGL producing field in California, one of the largest fields in the

continental U.S.1, >3,000 producing wells

  • 11 billion OOIP (BOE) and cumulative production of over 2.7 billion BOE
  • 2017 average net production of 53 MBOE/d (~40% of total CRC production)

Fie ield ld Map Producti roduction

  • n Histor
  • ry

Large fee property position with integrated infrastructure

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Raymond James and Associates 39th Annual Institutional Investors Conference | 15

Buena Vista Area – Highly Prospective Area

FIELDMAP

Ove Overvie view

  • Includes Buena Vista (BV) Hills and BV Nose
  • JV capital applied to infill development program that led to improved
  • perational efficiencies
  • Organic capital deployed to expand the extent of the play
  • BV Nose was discovered in 2012 as a step-out to BV Hills
  • 10,000’ average True Vertical Depth
  • 32 API, 600 GOR
  • Reduced capital costs with a new well design (two strings)

Growth potential near existing infrastructure

34 21 10 20 30 40 2012-14 2017 Drilling Time Days/well

5.0 2.5 100 200 300 400 500

  • 1.0

2.0 3.0 4.0 5.0 6.0 2012-14 2017 Drilling Cost $/Ft Drilling Cost $MM/well Drilling Cost/Well Drilling Cost $/Ft

2017 Conventional BV Nose Development Drilling Cost Average Drilling Days/Well

2017 BV Area development program delivers a 1.8 VCI at a $55 Brent price deck

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Raymond James and Associates 39th Annual Institutional Investors Conference | 16

Los Angeles Basin – Kitchen is the Entire Basin

Ove Overvie view

  • World-class hydrocarbon-rich sedimentary basin with large

quantities of stacked pay

  • ~10 billion barrels OOIP in CRC fields
  • Kitchen is the entire basin, hydrocarbons did not migrate

laterally; basin depth (>30,000 ft)

  • Very few penetrations >10,000 ft, leaving deep horizons

underexplored

  • Focus on mature waterfloods with generally low technical

risk and proven repeatable technology across huge OOIP fields

  • 2017 average net production of 27 MBOE/d (100%

liquids)

  • Over 30,000 net mineral acres
  • Major properties are premier coastal development assets
  • f Wilmington and Huntington Beach
  • The Wilmington field is subject to contractual agreements

similar to production-sharing contracts (PSCs). The contracts represented slightly less than 20% of our Total 2017 production.

Wilmington Huntington Beach

Basin in Map

33% of CRC’s 2017 oil production is from the Los Angeles Basin

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Raymond James and Associates 39th Annual Institutional Investors Conference | 17

Ventura Basin – Birthplace of the California Oil Industry

Over Overvie view

  • Prolific basin with a long history, including the first commercial oil well

in California

  • ~8 billion barrels OOIP in CRC fields
  • Operate 28 fields (over half the fields in the basin)
  • ~250,000 net mineral acres (75% undeveloped)
  • 2017 average net production of 6 MBOE/d (67% oil)
  • Portfolio of drive mechanisms: Primary, New & Redevelopment

Waterfloods and Steamfloods

  • Building off exploration success: recent exploration wells have flowed in

excess of 1,000 BOE/d along Oak Ridge trend

  • Incorporating 10 square miles of 3D seismic into drillable locations
  • Significant upside: movable oil, low recovery factor, controlling acreage

position and existing infrastructure

  • California wildfires in Ventura County impacted December 2017

production by approximately 2,000 BOE/d and production remained affected by approximately 1,000 BOE/d in January 2018

High Growth Area: large OOIP, low recovery factor and potential for high-IP wells

Fie ield ld Map

OOIP (MMBO) CUM PROD (MMBO) RF 7,843 813 10%

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Raymond James and Associates 39th Annual Institutional Investors Conference | 18

Sacramento Basin – Significant Gas Optionality

Ove Overvie view

  • Exploration started in 1918 and focused on seeps and topographic highs. In

the 1970s the use of multifold 2D seismic led to largest discoveries

  • Cretaceous Starkey, Winters, Forbes, Kione, and the Eocene Domengine

sands

  • Most current production under 6,000 feet, deeper targets remain at less

than 10,000 feet

  • 3D seismic surveys in mid-1990s helped define trapping mechanisms and

reservoir geometries

  • 2017 average net production of 33 MMcf/d (100% dry gas)
  • CRC produces 85% of basin gas with synergies from scale

California imports >90% of its natural gas requirements

Basin in Map

20 Miles

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Raymond James and Associates 39th Annual Institutional Investors Conference | 19 Drilling JV - Capital Workover Development Facilities Exploration Other1 Other1 San Joaquin Ventura Los Angeles

Producti roduction

  • n Enh

nhancemen ancement Plans ns for 2018

  • CRC 2018 capital plan will be directed to oil-weighted projects in our core fields: Elk Hills,

Wilmington, Kern Front, Huntington Beach, and continued delineation of Kettleman North Dome and Buena Vista

  • JV capital will be focused in the San Joaquin Basin and Huntington Beach
  • We have a dynamic plan that can be scaled up or down depending on the price environment

and efficient deployment of joint venture proceeds

2018 Capital Investment Program – Living Within Cash Flow

  • Approx. $425 to $450 million

1Other includes maintenance and occupational health, safety and

environmental projects, seismic and other investments.

2018E Total

  • tal Capita

tal Pla lan 2018E Dril illing ing Capita tal l – By Drive ive

28% 30% 22% 12% 4%4% 10% 10%

Conventional Exploration Waterfloods Steamfloods Unconventional

42% 6% 30% 16% 80%

The JV capital increases flexibility or provides for incremental deleveraging

  • Approx. $250 million
  • Approx. $250 million

6%

2018E Dril illing ing Capita tal l – By Basin in

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Raymond James and Associates 39th Annual Institutional Investors Conference | 20

0.9 1.0 1.1 1.2 1.3 1.4 1.5 1.6 1.7 0% 10% 20% 30% 40% 50%

PROJECT VCI DISCOUNT ON SECOND LIEN NOTES

PROJECT VS. SECOND LIEN (2L) NOTE REPURCHASE*

INVEST

If the VCI of an investment opportunity falls above the indifference curve, investing in the new project could be a better option

PURCHASE DEBT

If the VCI of an investment opportunity falls below the indifference curve, repurchasing 2L notes could be a better option

Example of Investment Alternatives for Asset Sale Proceeds

Per the terms of the 2014 credit agreement on asset sales, 2L notes must be repurchased at a minimum 20% discount to par Indifference Curve *CRC will continue to review all opportunistic debt reduction transactions. We utilize our Value Creation Index (“VCI”) to guide management in allocating capital and prioritizing investments.

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Raymond James and Associates 39th Annual Institutional Investors Conference | 21

History of Proactive Strategic Decisions

Swift, decisive actions through the commodity downturn have positioned CRC for growth. Proactive discussions with lenders and solid asset base provide a path to recovery and an actionable inventory.

5 10 15 20 25 30

$0 $20 $40 $60 $80 $100 $120

07/06/14 10/06/14 01/06/15 04/06/15 07/06/15 10/06/15 01/06/16 04/06/16 07/06/16 10/06/16 01/06/17 04/06/17 07/06/17 10/06/17 01/06/18

CRC Drilling Rig Count Brent Crude Oil Price ($/Bbl)*

Oil Price CRC Rig Count

  • 1. Cut rig count/began hedging
  • 4. Deleveraging Transactions
  • 2. Cut 2015 Capital Budget
  • 5. Increasing activity, invest within Cash Flow
  • 3. Bank Amendments
  • 6. JV Transactions

2 1 5 3

Under OXY

6

SPIN-OFF

3 3 3 3 3 4 4 4 4 6 6 3

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Raymond James and Associates 39th Annual Institutional Investors Conference | 22 70 80 90 100 110 120 130 140

2017 2018E 2019E 2020E 2021E

Oil Production MB/d

400 800 1,200 1,600 2,000 2017 2018E 2019E 2020E 2021E

EBITDAX $MM

Portfolio Flexibility Provides Range of Crude Oil Scenarios

Note: Scenarios assume flat pricing from $55 to $75 Brent and $3.00 to $3.10 NYMEX gas, respectively. Assumes lease operating costs are equal to 2017 levels for the mid-point of the range of planning scenario outcomes. Ranges of portfolio planning scenario outcomes assume development of a variety of combinations of steamflood, waterflood, conventional and unconventional projects in our inventory and reflect estimates of geologic, development and permitting risk. All discretionary cash flow reinvested in business for each scenario. * See www.crc.com Investor Relations for a description of the calculation of debt-adjusted per share and other important information.

Combined with mid-cycle commodity prices, we are positioned for growth in:

  • Cash flow
  • Production
  • Reserves
  • n a debt-adjusted per share basis*

Portfolio Planning Scenarios Portfolio Planning Scenarios

Capital focused on oil projects that provide Increa easi sing Margin ins Low w Decline line Rates es Compoun

  • undin

ding Cash sh Flow

+ =

  • Estimated Crude Oil Production Outcomes

Estimated Range of EBITDAX Outcomes

≈ ≈

300 600 900 1,200 1,500

2017 2018E 2019E 2020E 2021E

Capital ($MM)

Estimated Ranges of Capital Investments

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Raymond James and Associates 39th Annual Institutional Investors Conference | 23

The Case for CRC: Investment Thesis Overview

Grow within cash flow Industry leading decline rate Integrated and complementary infrastructure

Maintain Production Production and Cash Flow Growth

Production Innovation Deep Inventory

Investment Case for CRC

World-class assets with significant inventory Resilient model that preserves optionality and protects downside Focused on value and poised for growth

Moved from defense to offense

Why Own CRC Now

Competitive Advantages

Disciplined portfolio management Potential for EBITDAX growth

500 1,000 1,500 2,000 2,500 2017 2018E 2019E 2020E 2021E

$MM Clear runway and available cash

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SLIDE 24

Appendix

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Raymond James and Associates 39th Annual Institutional Investors Conference | 25

CRC Focus

Post-Spin Transformation

Culture Regulatory Engagement Employee Engagement

Silo / Separate Reactive Low One CRC Proactive High

Financial Priorities

$

Net Debt Capital Efficiency Annual Production Costs

$7BN Low $1.2BN $4BN High $750MM

Portfolio Management

Maintenance Capital Product Focus Actionable Inventory

High Rate Low Low Value High

Strategic Flexibility

Capital Flexibility Production Growth Trajectory Price Outlook

Preservation Decline Trough Acceleration Growth Peak

$

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Raymond James and Associates 39th Annual Institutional Investors Conference | 26

$3.26 $3.14 $2.95 $3.00 $2.75 $2.42 $3.09 $2.90 $2.47 $2.56 $2.77 $2.66 $2.28 $2.67

0.00 0.50 1.00 1.50 2.00 2.50 3.00 3.50

1Q 2017 2Q 2017 3Q 2017 4Q 2017 2015 2016 2017

$/Mcf

NYMEX Realizations

CRC – Price Realizations

66% 62% 72% 79% 40% 52% 70% 63% 59% 66% 72% 37% 50% 65% 0% 20% 40% 60% 80% 100% 1Q 2017 2Q 2017 3Q 2017 4Q 2017 2015 2016 2017 % of WTI & Brent WTI Brent $51.91 $48.29 $48.21 $55.40 $48.80 $43.32 $50.95 $50.24 $47.98 $50.02 $56.92 $49.19 $42.01 $51.24 $54.66 $50.92 $52.18 $61.54 $53.64 $45.04 $54.82 30 40 50 60 70 1Q 2017 2Q 2017 3Q 2017 4Q 2017 2015 2016 2017 $/Bbl WTI Realizations Brent Realization %

  • f WTI

97% 99% 104% 103% 101% 99% 101% Realization %

  • f NYMEX

89 % 79% 87% 92% 97% 94% 86%

Oil il Pric ice Realizati lization n (wit ith h Hedges) ges) Gas Pric ice Realizati lization NGL Price e Realization ation - % of W WTI & B Brent

CRC believes near-term differentials will remain strong

  • California refinery demand for native crude continues to be strong

and reduction in heavy waterborne crude has positively influenced differentials.

  • NGL prices have been supported by lower inventories and export

markets.

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Raymond James and Associates 39th Annual Institutional Investors Conference | 27

Summary of Amendment to the 2014 Credit Facility

1 Defined as indebtedness outstanding under 2014 Credit Facility to LTM Consolidated EBTIDAX.

Note: The full amendment was filed with Form 8K on November 13, 2017.

Descri cript ption ion

Revolv volver er Commit itmen ent

  • 2014 Credit Facility consisting of $1.0 billion 2014 Revolver

2017 Term Loan n Indeb ebtedn ednes ess

  • Permit a $1.3 billion first lien term loan (the “2017 Term Loan”)
  • Proceeds from 2017 Term Loan, net of 2% original issue discount, fees and expenses, used to completely repay the 2014 Term Loan and pay down the

2014 Revolver Maturit rity Extensio ion

  • June 30, 2021

Non-Bor

  • rrowing

ing Base Asset et Sale e Proceeds eeds

  • Net Cash Proceeds may be used to prepay junior indebtedness so long as Liquidity > $250 million, such prepayment occurs at least at a 20% discount to

par and subject to the following: – 25% of the proceeds up to $500 million (excluding the Elk Hills Power Plant) shall be applied to repay drawings under the 2014 Revolver – 50% of the proceeds in excess of $500 million and less than $1 billion (excluding the Elk Hills Power Plant) shall be applied to repay drawings under the 2014 Revolver – 75% of the proceeds in excess of $1 billion (excluding the Elk Hills Power Plant) shall be applied to repay the 2014 Revolver and reduce commitments by a corresponding amount – 50% of the proceeds of the Elk Hills Power Plant shall be applied to repay drawings under the 2014 Revolver Financ ancial ial Coven venants nts

  • 2014 Credit Facility Leverage Ratio1:

– 2017-2019: ≤ 1.90x – 2020-2021: ≤ 1.50x

  • Minimum Interest Coverage Ratio: 1.20x
  • First Lien Asset Coverage Ratio: 1.20x
  • Minimum Liquidity: $150 million, tested monthly

Other r Terms

  • Incremental commitment capacity limited to $50 million
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Raymond James and Associates 39th Annual Institutional Investors Conference | 28

Strategic Partner Alignment

Summary of Deal Partner

▪ Affiliate of Ares Management (Ares)

Contributed Assets

▪ Elk Hills power plant, gas processing assets and related non-borrowing base infrastructure currently owned by CRC

Midstream JV Capitalization

▪ Class A common interests (voting) owned 50% by Ares and 50% by California Resources Elk Hills (CREH) ▪ Class B preferred interests (“Preferred”) owned 100% by Ares ▪ Class C common interests (distributing) owned 95.25% by CREH and 4.75% by Ares

Distribution to Partners

▪ Preferred interests to receive distributions of 13.5% per annum on the $750 MM contributed amount ▪ 9.5% cash pay and 4.0% PIK to be deferred for the first three years ▪ Deferred distributions are interest bearing and repaid over two years following the deferral period ▪ Remaining cash after preferred distributions to be distributed pro rata to Class C interests

Exit Provisions

▪ Prior to end of 5 or 7.5 years, CRC may redeem Preferred at variable amounts that include make whole premiums ▪ At end of 5 years, CRC may elect to either redeem or extend to 7.5 years ▪ At 7.5 years, if not redeemed by CRC, Preferred can monetize the JV

Board

▪ Board of Managers to consist of three CRC representatives and three representatives from Ares

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SLIDE 29

Raymond James and Associates 39th Annual Institutional Investors Conference | 29

CRC Midstream JV Structure with Ares

California Resources Elk Hills, LLC Elk Hills Power, LLC

Contributed Assets $750 MM gross proceeds Class A (50%) and Class C (95.25%) Common Interests Power and Gas Processing Services Commercial Agreement Capacity Charges

Ares Management, L.P.

$750 MM gross proceeds Class B Preferred Interests, Class A and Class C Common Interests

Benefits

  • Strategic alignment with Ares
  • Provides CRC paths for opportunistic

deleveraging through cash flow growth

  • r debt reduction
  • Greatly enhances liquidity
  • Retain ownership and operational

control

  • Defined exit criteria
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SLIDE 30

Raymond James and Associates 39th Annual Institutional Investors Conference | 30

2014 Revolving Credit Facility Capacity - $1 billion

Updated Capital Structure from Recent Transactions – Improved Liquidity

2017 Term Loan - $1.3 billion 2016 Term Loan - $1 billion 2015 Second Lien - $2.25 billion Unsecured Notes - $0.393 billion

Drawn Revolver $837 $0 $250 $500 $750 $1,000

3Q17 PF 4Q17* ($MM)

Revolver Availability $431 Revolver Availability $850 Cash $11 Cash $441 $0 $200 $400 $600 $800 $1,000 $1,200 $1,400

3Q17 PF 4Q17* Availability ($MM)

Increased eased Liqui uidity** dity**

* Pro Forma for the Ares JV and $50mm private placement ** Subject to minimum liquidity requirement under 2014 Revolving Credit Facility. Includes unrestricted cash.

Reduc uced ed Revo volver er Borro rowing ng Added in November Debt Hierarchy

Undr drawn Revolv volver er

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SLIDE 31

Raymond James and Associates 39th Annual Institutional Investors Conference | 31

Significant Reduction in Net Debt from Post-Spin Peak

6,7651 4,502 3,000 4,000 5,000 6,000 7,000

2Q15 Debt Exchange for 2L Open Market Repurchases Equity for Debt Exchange Cash Tender for Unsecureds Cash Flow Ares Transactions PF 4Q17

Total Net Debt ($ MM)

2

Cumulative Net Debt Reduction Total

Total Net Principal Reduction $535 million $153 million $102 million $625 million $59 million $789 million $2,263 million

1 Represents mid-second quarter 2015 peak debt. 2 Includes operating cash flow, positive working capital and proceeds from asset sales in 1H 2017, net of restricted cash. 3 Pro Forma net debt at 4Q17 includes the payoff of the 12/31/2017 outstanding balance of $363 million on our RCF and $441 million of available cash after the completion of the Ares transactions.

  • Chose options to maximize deleveraging and minimize recurring cost to the income statement on a per share basis.

Continue to seek opportunistic transactions that reduce overall debt.

3

slide-32
SLIDE 32

Raymond James and Associates 39th Annual Institutional Investors Conference | 32

1Q 2018 2Q 2018 3Q 2018 4Q 2018 1Q 2019 Sold Calls Barrels per Day 9,000 6,200 16,100 16,100 1,100 Weighted Average Ceiling Price per Barrel $59.58 $60.24 $58.91 $58.91 $60.00 Purchased Calls Barrels per Day

  • 2,000

Weighted Average Ceiling Price per Barrel

  • $71.00

Purchased Puts Barrels per Day 1,200 1,200 6,100 1,100 14,100 Weighted Average Floor Price per Barrel $45.82 $45.83 $61.48 $45.85 $58.93 Sold Puts Barrels per Day 29,000 29,000 24,000 19,000 10,000 Weighted Average Floor Price per Barrel $45.00 $45.00 $46.04 $45.00 $47.50 Swaps Barrels per Day 38,300 34,000 19,000 19,000 7,000 Weighted Average Price per Barrel $60.03 $60.00 $60.13 $60.13 $67.71 Percentage of 4Q 2017 Oil Production Hedged* 49% 49% 44% 31% 25% 25% 26% 26%

Opportunistically Built Oil Hedge Portfolio

Certain of our counterparties have options to increase swap volumes at weighted average costs between $60 and $70 Brent. For potential volume changes and further details please see Attachment 10 of our Earnings Release. * Assumes counterparty options are not exercised.

We target hedges

  • n 50% of crude
  • il production

Strategy

Protect cash flow for capital investments and covenant compliance

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Raymond James and Associates 39th Annual Institutional Investors Conference | 33

Accelerating Production Decline in U.S. Onshore Lower 48 Development Wells

  • 50%
  • 40%
  • 30%
  • 20%
  • 10%

0% 10% 20% 30% 40% Year 1 Year 2 Year 3 Year 4 Year 5

Normalized Decline Rates

2010 Wells 2011 Wells 2012 Wells 2013 Wells 2014 Wells 2015 Wells Source: Data from Wood Mackenzie, CRC analysis

Recent wells in the onshore Lower 48 are showing steeper declines

  • 1,000,000

2,000,000 3,000,000 4,000,000 5,000,000 6,000,000 7,000,000 2009 2010 2011 2012 2013 2014 2015 2016

Production (BOPD)

Pre 2010 2010 Wells 2011 Wells 2012 Wells 2013 Wells 2014 Wells 2015 Wells

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SLIDE 34

Raymond James and Associates 39th Annual Institutional Investors Conference | 34

0% 10% 20% 30% 40% 50%

1 Year Decline

Median: 29%

Best In Class Corporate Decline Rates

0% 10% 20% 30% 40% 50% 60% 70% 80%

3 Year Decline

Median: 49%

CRC CRC

Peers included: CLR, COG, CPE, CXO, DNR, EGN, EOG, EPE, FANG, HK, LPI, MRO, MTDR, MUR, NFX, OAS, PDCE, PE, PXD, QEP,RRC, RSPP, SM, SN, WLL,WPX, and XEC. Source: Wood Mackenzie - Operated Production Data through 2016, CRC analysis. FY 2016 Production Percentage Liquids Less than 55% 55% - 75% Greater than 75%

slide-35
SLIDE 35

Raymond James and Associates 39th Annual Institutional Investors Conference | 35

Core Principle of Living within Cash Flow

(2,500) (2,000) (1,500) (1,000) (500)

  • 500

1,000 1,500

Unlevered Free Cash Flow ($MM)

CRC

Peers included: APA, APC, AR, BBG, CHK, CLR, COG, CPE, CRK, CRZO, CXO, DNR, DVN, ECR, EGN, EOG, EPE, EQT, FANG, GPOR, GST, HK, JONE, LPI, MRO, MTDR, MUR, NBL, NFX, OAS, PDCE, PE, PXD, QEP, REI, RICE, RRC, RSPP, SD, SGY, SM, SN, SWN, UNT, UPL, VNR, WLL, WPX, and XEC. Source: FactSet.

2016 Unlevered Free Cash Flow

Average: $(293.5)MM

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SLIDE 36

Raymond James and Associates 39th Annual Institutional Investors Conference | 36

Accelerating Value and Derisking Inventory through JVs

Highlights:

  • Up to $300MM

― Initial commitment of $160MM

  • DrillCo type structure where Investor funds

100% of project capital for 90% WI, with CRC carried on its 10% WI ― CRC interest reverts to 75% after target IRR is achieved ― CRC retains early termination options

  • Focus on four fields within the San Joaquin

Basin ― Kern Front, Mt. Poso, Pleito Ranch, Wheeler Ridge

  • CRC operates all wells

Highlights:

  • Up to $250MM over ~2 years

― Two tranches of $50MM ― Total of $100MM funded

  • Investor funds 100% of project

capital in exchange for a net profits interest (NPI) ― Investor NPI interest reverts to CRC after low teens target IRR ― CRC retains early termination

  • ptions
  • Current focus is in the San Joaquin

Basin

  • CRC operates all wells
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SLIDE 37

Raymond James and Associates 39th Annual Institutional Investors Conference | 37

  • 1,000.00

2,000.00 3,000.00 4,000.00 5,000.00 6,000.00 7,000.00 1 4 7 10 13 16 19 22 25 28 31 34 37 40 43 46 49 52 55 58 61 64 67 70 73 76 79 82 85 88 91 94 97 100103106109112115118 JV Share Typical E&P Share

Typical Industry JV Structure

  • Based on recent industry JV

deals, a typical deal structure is

  • Partner pays 80-100% Capital
  • Receives 80-100% Working

Interest

  • Typical hurdle rate:
  • 10% - 20% IRR
  • Partner’s working interest once

hurdle rate is achieved:

  • 5% - 25%

Hurdle Rate Reached

Production Time

slide-38
SLIDE 38

Raymond James and Associates 39th Annual Institutional Investors Conference | 38

Dynamic Portfolio Provides Flexibility

200 400 600 800

BOEPD

YEAR 5 200 400 600 800

BOEPD

YEAR 5

Gas

200 400 600 800

BOEPD

YEAR 5

0% 25% 50% 75% 100%

Portfolio Mix Higher Oil to Gas Price Ratio Lower Oil to Gas Price Ratio

Gas Unconventional Primary Waterflood Steamflood Workover

EUR (MBOE per $10MM) 1,385 1,265 1,060 % Oil 81% 70% 53% Development Cost/BOE $7.20 $7.90 $9.40 Recycle Ratio 3.4x 2.9x 2.2x

For illustration of portfolio optionality based on normalized results per $10MM of investment and not guidance. See endnote for details on type curves. Prices for recycle ratio are $65 Brent and $3.50 NYMEX.

Oil Gas Oil Oil Gas

slide-39
SLIDE 39

Raymond James and Associates 39th Annual Institutional Investors Conference | 39

0. 0.0 1. 1.0 2.0 2.0 3. 3.0 4. 4.0

VCI

Kern Front Buena Vista Bardsdale Asphalto Grimes Lost Hills Elk Hills Buena Vista Nose Buena Vista Kettleman McDonald Anticline Huntington Beach Elk Hills Elk Hills Rio Vista McKittrick Kettleman Kettleman Gunslinger Tompkins Hill Midway Sunset Mount Poso Montalvo Kettleman Willows North Antelope Hills Paloma Paloma North Shafter Oxnard Rincon Pleito Ranch Railroad Gap South Mountain Rio Viejo Rose San Miguelito South Mountain Wilmington Saticoy Wheeler Ridge Yowlumne

Steamfloods Primary Waterfloods Shales Gas

All economics are pre-tax. VCI range by project is summarized from ‘Type Wells by Mechanism’ in subsequent slides. Low end of range assumes $55 Brent and high end assumes $75 Brent and $3.50 NYMEX.

Multiple Recovery Methods with High Value Creation

1.3 VCI implies $1.30 of PV-10 for every $1 invested

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SLIDE 40

Raymond James and Associates 39th Annual Institutional Investors Conference | 40

25 50 75 100 1 2 3 4 BOPD YEAR

* Information is for a steamflood pattern assuming 3 producers per 1 injector and is fully burdened with new steam generator infrastructure costs of $900K per pattern. At low prices, new steam generation infrastructure is not added to the project. See endnotes for important information about our type curves.

PARAMETERS PER PATTERN Operating Expense/bbl

$10-20

Capital Cost *

$2.8MM

Total EUR (MBO)

270

Peak Rate (BOPD)

90

D&C (days)

15

Royalty

10%

Greenfield Steamflood Type Pattern

Composite Type Curve Kern Front Actuals

CRC OPERATED FIELDS

Oxnard Midway Sunset McKittrick McDonald Anticline Kern Front Lost Hills

  • N. Antelope

Hills

CRC STEAMFLOODS

300 Near Term Growth Plan Pattern Locations

$NYMEX

VCI

$3.5 $3 $2.5 $50 1.0 1.1 1.2 $55 1.3 1.4 1.5

$ BRENT

$60 1.6 1.7 1.8

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Raymond James and Associates 39th Annual Institutional Investors Conference | 41

15 30 45 60 1 2 3 4 BOEPD YEAR

* Capital cost is fully burdened with facilities, injectors and tie-ins. Assumes 5-spot pattern with a 1:1 producer to injector ratio.

VCI

165 190

EUR

215 $50 1.3 1.5 1.7 $55 1.6 1.9 2.1

$ BRENT

$60 1.9 2.2 2.5

Waterflood – New Pattern Composite Type Well

Composite Type Curve

Mount Poso Actuals Buena Vista Actuals

CRC OPERATED FIELDS

Rincon Saticoy South Mountain Paloma Mount Poso Kettleman Buena Vista Elk Hills

CRC NEW & POTENTIAL WATERFLOODS

See endnote for important information about our type curves.

350 Near Term Growth Plan Locations

PARAMETERS PER PATTERN Operating Expense

$19/BOE

Capital Cost*

$1.2MM

Total EUR (MBOE)

190

Peak Rate (BOEPD)

35

Drilling Time (days)

10

Royalty

12.5%

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Raymond James and Associates 39th Annual Institutional Investors Conference | 42

40 80 120 160 1 2 3 4 BOEPD YEAR

* Capital cost is fully burdened with facilities, injectors and tie-ins. ** A majority of locations are subject to PSCs, which have a 49% NPI. For NPV calculation, this can be modeled as 49% WI/NRI. For Production Rate, Net/Gross ratio is typically 75% when including cost recovery barrels. See endnote for important information about our type curves.

PARAMETERS Operating Expense

$19/BOE

Capital Cost*

$1.8MM

Total EUR (MBOE)

165

Peak Rate (BOEPD)

120

Drilling Time (days)

14

Royalty

PSC**

VCI

140 165

EUR

190 $50 1.1 1.3 1.5 $55 1.4 1.6 1.9

$ BRENT

$60 1.6 1.9 2.2

Waterflood – Redevelopment Type Well

Huntington Beach Actuals Elk Hills Actuals Composite Type well West Wilmington Actuals East Wilmington Actuals

CRC OPERATED FIELDS

San Miguelito Elk Hills Wilmington Huntington Beach

CRC REDEVELOPMENT WATERFLOODS

350 Near Term Growth Plan Locations

slide-43
SLIDE 43

Raymond James and Associates 39th Annual Institutional Investors Conference | 43 PARAMETERS Operating Expense

$10/BOE

Capital Cost*

$5.0MM

Total EUR (MBOE)

430

Peak Rate (BOEPD)

360

Drilling Time (days)

30

Royalty

12%

* Capital cost includes drilling, completion, and tie-ins. Does not include 450 shallow (<5,000 ft) locations with costs under $1.5 MM/well and with similar economics.

Primary Type Well – Deeper Horizons

VCI

400 430

EUR

460 $50 1.5 1.6 1.7 $55 1.7 1.8 2.0

$ BRENT

$60 1.9 2.1 2.2

150 300 450 600 750 900 1 2 3 4 BOEPD YEAR

Composite Type well Wheeler Ridge Actuals Bardsdale Actuals Pleito Ranch Actuals BV Nose Actuals

CRC OPERATED FIELDS

Montalvo Kettleman Saticoy Bardsdale South Mountain Elk Hills BV Nose Yowlumne Pleito Ranch Wheeler Ridge Paloma Rio Viejo

CRC PRIMARY

See endnote for important information about our type curves.

150 Near Term Growth Plan Locations

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Raymond James and Associates 39th Annual Institutional Investors Conference | 44

California Shale Type Well

Asphalto Elk Hills Buena Vista Kettleman Rose

  • N. Shafter

Gunslinger Railroad Gap

CRC SHALE

  • 100

200 300 400 500

1 2 3 4

BOEPD

New Pool Type Curve Infill Shale Curve

YEAR

Gunslinger Actuals Rose/N. Shafter Actuals Elk Hills Actuals Elk Hills (2001-2003) VCI

Infill New Pool $50 1.2 1.7 $55 1.3 1.9

$ BRENT

$60 1.4 2.0

*Capital cost includes drilling, completion and tie-ins. See endnote for important information about our type curves.

New Pool Operating Expense

$10/BOE $8/BOE

Capital Cost*

$5.0MM $2.5MM

Total EUR (MBOE)

765 220

Peak Rate (BOEPD)

500 143

Drilling Time (days)

30 20

Average Royalty

13% 13%

Infill

50 Near Term Growth Plan Locations (Split Evenly)

CRC OPERATED FIELDS

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SLIDE 45

Raymond James and Associates 39th Annual Institutional Investors Conference | 45

A Net Water Supplier

  • For every gallon of fresh water CRC purchased in 2017, we

delivered nearly 3 gallons of treated water to agriculture

  • Recycled or reclaimed over 89% of our produced water in

2017, almost a 10% increase since 2015

  • Reduced our produced water disposal by over 40% since 2015
  • Reduced our potable water use by nearly 30% since 2015

In 2017, CRC supplied 4.9 billion gallons – over 15,000 acre-feet – of treated, reclaimed water for irrigation or recharge.

94% 4% 2%

WA WATER ER MANAGE GED IN CRC’s OPERATIONS

Produced Water Fresh Water Non-Fresh Water

CRC set a new company record for water deliveries to agriculture in 2017, an 85% increase since 2015, preserving farmland and jobs. CRC’s operations in Long Beach use recycled or non-fresh water for 99.5% of their total water use.

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SLIDE 46

Raymond James and Associates 39th Annual Institutional Investors Conference | 46

End Notes

1 Current CRC estimate of reserves value as of December 31, 2017. Includes field-level operating expenses and G&A. Assumes

$3.00/MMBTU NYMEX.

2Reflects the value of facilities and midstream assets at 50% of estimated replacement value. This discount is estimated to exceed

the burden on reserves that would be incurred if assets were monetized. Excludes the value of the assets monetized in the Ares transaction.

3 Surface & Minerals reflect the estimated value of undeveloped surface and minerals held in fee. 4 Unproved inventory comprises risked probable and possible reserves and contingent and prospective resources. Contingent and

prospective resources consist of volumes identified through life-of-field planning efforts to date.

5 Calculated using December 31, 2017 debt at par and market cap as of February 19, 2018.

Type Curve Note: Each field-specific type well curve represents an average of the historical results of multiple projects over the prior four-year time period. Drive mechanism type curves are the weighted average of the field-specific curves related to the projects chosen for our near-term growth plan. Type curves represent management’s estimates of future results and are subject to project selection and other variables. Our type well curves are prepared for purposes of modeling overall results of our near-term growth program and are not useful for purpose of benchmarking any individual well or pattern performance. Actual results are expected to vary depending on which projects are specifically developed. Value Creation Index (VCI) Note: VCI is calculated by dividing the net present value of the project’s expected pre-tax cash flow over its life by the net present value of the investments, each using a 10% discount rate