EX-99.1 2 dex991.htm PRESENTATION Presentation
Deutsche Bank
2008 Small and Mid Cap Growth Conference
Exhibit 99.1

1
Forward Looking Statements
This presentation includes forward-looking information that are subject to a
number of risks and uncertainties, many of which are beyond our control. All
information, other than historical facts included in this presentation,
regarding our strategy, future operations, drilling plans, estimated reserves,
future production, estimated capital expenditures, projected costs, the
potential of drilling prospects and other plans and objectives of management
are forward-looking information. All forward-looking statements speak only
as of the date of this presentation. Although the Company believes that the
plans, intentions and expectations reflected in or suggested by the forward-
looking statements are reasonable, there is no assurance that these plans,
intentions
or
expectations
will
be
achieved.
Actual
results
may
differ
materially
from
those
anticipated
due
to
many
factors,
including
oil
and
natural gas prices, industry conditions, drilling results, uncertainties in
estimating reserves, uncertainties in estimating future production from
enhanced recovery operations, availability of drilling rigs and other services,
availability of oil and natural gas transportation capacity, availability of
capital resources and other factors listed in reports we have filed or may file
with the Securities and Exchange Commission.

2
Company Overview
Completed IPO on May 14 at $15 (CLR on NYSE)
$4 billion market capitalization
Founded 1967 by Harold Hamm, Chairman & CEO
Harold Hamm, family and management own 82%
Organic growth strategy focused on unconventional resource plays
3Q 2007 daily production 29,474 boe
> 2X 2004 level of 14,121 boepd
>500 hz
wells drilled targeting unconventional formations
>700,000 net undeveloped acres concentrated in emerging plays
Strong financial results
3Q 2007 EBITDA $132,187 > full year 2004 $116,498
9M 2007 cash operating margin of $42/boe ($7/Mcfe) -
$66 NYMEX
$156 million of bank debt outstanding as of 9/30/07

3
Investment in Asset Base
Capex ($mm)
Production (boepd)
2007 Capex by Region ($mm)
2008 Capex by Region ($mm)

4
Operational Overview
Mid-Continent
Proved reserves: 24.3 MMboe
Gulf Coast
Proved reserves: 0.3 MMboe
Red River
Units
50%
Bakken
Field
25%
Other Rockies -
7%
Mid-Continent
11%
Gulf Coast
<1%
Total proved reserves (12/31/07) = 134.6 MMboe
74% PD /  77% oil / 11.1 R/P / Operate 93% of PV-10%
Unconventional
82%
Red River
Units
46%
Bakken
Field
30%
Other Rockies -
6%
Mid-Continent
14%
Gulf Coast
1%
Avg. daily production (Q3 2007) = 29.5 Mboepd
Unconventional
79%
1,223 net producing wells with
>1,000 net drilling locations
Rockies
Proved reserves: 110.0 MMboe
Proved Reserves by Geography
Production by Geography
Woodford -
3%
Woodford -
7%
Headquarters    
Regional office
Counties with acreage holdings
are highlighted

5
Key Drilling Projects
Development (41% 2008 capex)
Red River Units
50% proved reserves / 46% production
Montana Bakken Shale
20% proved reserves / 26% production
Emerging Plays (42% 2008 capex)
North Dakota Bakken Shale
300,000 net acres
Oklahoma Woodford Shale
45,000 net acres
Red River
Units
MT
Bakken
ND
Bakken
Woodford
Counties with acreage    
holdings are highlighted
Regional office 
Headquarters
Development
Emerging Plays

6
Red River Enhanced Recovery Units
67.9 MMboe
proved reserves
13,524 net boepd
in 3Q 2007
Cedar Hills discovered in 1995
Developed with hz
drilling
2003 enhanced recovery operations
2008 Plans
$168MM capex
Infield horizontal drilling and re-entry drilling
program to accelerate production and
enhance sweep efficiency
Develop Cedar Hills on 320 acre / producer
Forecast 2009 peak at ~19 net Mboepd
Cedar Hills North Unit
Cedar Hills West Unit
Buffalo Units
Medicine Pole
Hills West Unit
Medicine Pole
Hills South Unit
Medicine
Pole Hills
Unit
25 Miles
CLR operated units
Others units

7
Montana Bakken Shale
Significant  unconventional oil
resource play
Represents ½
of Montana’s
oil production
CLR largest producer
(7,637 net boepd)
Developed through horizontal
drilling and advanced fracture
stimulation
2008 Plans
$55MM capex
13 net wells
Opportunities:
320-acre infill drilling
Expansion of field with      
tri-lateral 640-acre wells
Enhanced recovery 
2 to 3 drilling rigs
CLR  acreage
35 miles
Horizontal
Bakken
producer
Williston    Basin
Richland Co.,
MT Bakken
Outline of 
potential
Bakken 
Production
Vertical
Bakken
producer

8
Richland County, Montana Bakken
Focus of 320-acre
spacing drilling
Focus of Tri-lateral
drilling
3-D defined
Red River C 
drilling
Sinclair Discovery
300 bopd

9
North Dakota Bakken Shale
Emerging  unconventional oil
resource play
300,000 net acres strategically
located on Nesson
Anticline
Significant reserve and production
growth potential
ND oil prod. highest in 20 years
40+ industry-operated rigs
Amerada Hess
Marathon
EOG Resources
ConocoPhillips
2008 Plans
$125MM capex
20 net wells
6 to 8 drilling rigs (including Conoco
Phillips JV)
CLR  acreage
35 miles
Horizontal
Bakken
producer
Williston    Basin
Outline of 
potential
Bakken 
Production
Vertical
Bakken
producer

10
North Dakota Bakken
LEGEND
CRI OPERATED
CRI NONOPERATED
NO CRI INTEREST
Normandy
Rocket
Galaxy
Norse
Valhalla
Pontiac
Focus of 2008 drilling
(consistent economic
results)
Encouraging results using
un-cemented liners and
multi-staged fracs
Testing un-cemented
liner and multi-staged
fracs
3 CLR rigs
3 COP rigs
Dev/Step-outs
1 CLR rig
Bakken, Fryburg
1 CLR rig
Bakken, Winnipegosis
EOG Parshall
Area

11
Oklahoma Woodford Shale
Outline of potential
Woodford production
07 CLR Locations
07 Woodford hz
Spud
CLR Producer
Woodford Producer
CLR Acreage
Exploration
Development step-outs/
downspacing
Emerging unconventional
gas resource play
30+ industry-operated rigs
Newfield
Antero
Devon
45,000 net acres
Significant reserve and
production growth potential
Caney Shale upside
2008 Plans
$103MM capex
20 net wells
5 to 6 drilling rigs
6 miles

12
ND Bakken
and OK Woodford Shale potential
222 MMboe
400,000
556
OK Woodford
Total
ND Bakken
98 MMboe
256,000
384
320 MMboe
Reserve potential
940
Net boe/well
Net potential
unbooked
locations (1)
(1) Assumed 640 acre spacing for
ND Bakken
and 80 acre for Woodford Shale
34%
27%
$70/bbl & $6/Mcf
Pre-tax IRR
50%
400,000
$5,000,000
OK Woodford
ND Bakken
38%
256,000
$4,750,000
$80/bbl & $7/Mcf
Pre-tax IRR
Net boe/well
Estimated
average
D&C

13
Other ongoing and emerging plays
Rockies:
175,000 net undeveloped acres
Red River, Winnipegosis,
Fryburg, Phosphoria, Lewis
Shale
Midcontinent:
180,000 undeveloped acres
Morrow-Springer, Atoka,
Mississipian, Hunton,
Woodford Shale,
Trenton/Black River
Gulf Coast:
5,000 net undeveloped acres
Frio, various GC sands
360,000 net undeveloped acres 
(~50% of total undeveloped acreage)
Recent discoveries:
MI –
Trenton/Black River
SD –
Red River B
MT –
Red River C
ND –
Winnipegosis
Counties with acreage    
holdings are highlighted
Regional office
Headquarters

14
Financial and Operating Summary
1 
See page 9 of the prospectus and third quarter 2007 earnings release for a reconciliation of net income to EBITDAX.
2
Operating statistics
per
Boe
sold.
Oil
sales
volumes
are
96
MBbls
and
47
MBbls
less
than
oil
production
volumes
for
2006
and
2007,
respectively.
Year ended December 31,
2004
2005
2006
9M
2007
Realized oil price ($/Bbl)
$37.12
$52.45
$55.30
$58.92
Realized natural gas price ($/Mcf)
$5.06
$6.93
$6.08
$5.82
Oil production
(boepd)
10,104
15,638
20,493
24,224
Natural gas production
(Mcfd)
24,093
24,674
25,274
31,499
Total production (boepd)
14,121
19,751
24,707
29,474
EBITDAX
($
thousands)¹
$116,498
$285,344
$372,115
$332,472
Key Operational Statistics ($/boe)
2
Oil and gas revenue
$35.20
$50.19
$52.09
$54.68
Production expense
8.49
7.32
6.99
7.53
Production tax
2.39
2.22
2.48
2.89
G&A (excluding non-cash equity compensation)
2.02
2.43
2.24
1.95
Total cash costs
$12.90
$11.97
$11.71
$12.37
Net operating margin
$22.30
$38.22
$40.38
$42.31

15
Summary
High quality, proved reserve base
Crude oil-concentrated, long-lived, high operated %
Track record of drill bit growth at low cost
Annual EBITDAX > Capex
over past 3 years
Low risk production growth in Red River Units
~5,500 boe/d
expected production growth over next 1+ year                  
(~18% of current daily production for entire company)
Significant future production and reserve growth opportunities in
two large emerging plays –
ND Bakken
and OK Woodford Shales
320 MMboe
potential reserves
Low cash costs with one of highest net operating margins
Significant valuation and competitive advantage