Continental Resources Inc (CLR) 8-K 2008 Small and Mid Cap Growth Conference

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