Georesources (GEOI) 8-K Information herein contains forward-looking statements that involve significant

GeoResources, Inc

Corporate Profile

October  2009

Exhibit 99.1

2

Forward-Looking Statements

Information herein contains forward-looking statements that involve significant

risks and uncertainties, including our need to replace production and acquire or

develop additional oil and gas reserves, intense competition in the oil and gas

industry,

our

dependence

on

our

management,

volatile

oil

and

gas

prices,

costs

associated with hedging activities and uncertainties of our oil and gas estimates

of proved reserves and reserve potential, which may be substantial.  In

addition,

all

statements

or

estimates

made

by

the

Company,

other

than

statements of historical fact, related to matters that may or will occur in the

future are forward-looking statements. 

Readers are encouraged to read our December 31, 2008 Annual Report on

Form 10-K/A and any and all our other documents filed with the SEC regarding

information about GeoResources

for meaningful cautionary language in respect

of the forward-looking statements herein.  Interested persons are able to obtain

free copies of filings containing information about GeoResources, without

charge, at the SEC’s

Internet site (http://www.sec.gov). There is no duty to

update the statements herein. 

3

Key Investment Highlights

Value Creation

Experienced Management and Technical Staff with  Large Ownership

•

Successful Track Record of Creating Value  and Liquidity for Investors

•

Board and Management own 53%

Attractive Value Proposition

•

Trading at a Discount to NAV

Strong Asset Base

•

Strategically Located

•

Geographically Diverse

•

Balanced Oil vs. Gas

•

High Level of Operating Control

Significant Identified Upside Potential on Existing Properties

•

Low Risk Development Potential (i.e. Austin Chalk, Bakken)

•

Higher Impact Exploration Potential (i.e.  Eagle Ford, Georgetown)

Strong Financial Position; Moderate Leverage, Significant Cash Flow

4

Company Overview

Company Highlights

Direct

Direct+

Ownership

Partnership

(1)

Proved Reserves (MMBOE)

(2)

22.5

24.3

Oil

52%

48%

Proved Producing

61%

62%

Proved Developed

74%

75%

PV 10% (millions)

$392.5

$419.1

Production (MBOEPD)

(3)

5.1

5.7

Operated

82%

82%

Gross Acreage

(4)

483,324

483,324

Net Acreage

(4)

224,377

234,427

(1)

Includes GEOI’s share of partnerships’ reserves.

(2)

Proved reserves presented throughout this profile are estimated as of 10/1/2009 and based on NYMEX strip pricing at 9/30/09.

(3)

October 2009, estimate.

(4)

Acreage information estimated as of  7/1/09.  Maps herein exclude minor value properties.

5

Balanced Growth Strategy

Asset

Rationalization

•

Selectively divest assets to upgrade portfolio.

•

Focus on maximizing IRR for investors.

Cost Control

•

Target low operating and G&A costs.

•

Minimize drilling and development costs.

•

Promoting partners reduces costs and generates operating fees.

•

Generate exploration projects.  Increase direct participation, with growth.

•

Solicit partners on a promoted basis.

Exploration

•

Acquire operated properties with producing reserves, development, and

exploration potential.

•

Solicit partners on a promoted basis.

Acquisitions

Development

Exploitation

•

Drill PUDs

and probable reserves to optimize value.

•

Focus on fields and projects with development and exploitation upside.

•

Re-engineering

and

development

programs

extend

field

life,

increase

proved

reserves, lower unit operating costs, and enhance economics.

6

Management History

2004-

2007

Southern Bay Energy, LLC

Gulf Coast, Permian Basin

REVERSE MERGED INTO

GEORESOURCES

2000-2007

Chandler Energy, LLC

Williston Basin, Rockies

ACQUIRED BY

GEORESOURCES

1988-2000

Chandler Company

Rockies, Williston Basin

MERGED INTO

SHENANDOAH THEN SOLD 

TO QUESTAR 

1992-1996

Hampton Resources Corp,

Gulf Coast

SOLD TO BELLWETHER

EXPLORATION

1997-2001

Texoil Inc.

Gulf Coast, Permian Basin

SOLD TO OCEAN 

ENERGY

2001-2004

AROC Inc.

Gulf Coast, Permian Basin,

Mid-Continent

LIQUIDATED FOR BENEFIT

OF SHAREHOLDERS

Track record of profits and liquidity.

Long-term repeat investors.

Extensive industry and financial

relationships.

Significant operations and financial

experience.

Cohesive management and technical

staff.

Team has been together for up to 20

years through multiple entities.

Refer

to

Company

webpage

at

www.georesourcesinc.com

for

additional

information.

7

Management Profiles

Name

Title

Experience

Frank A. Lodzinski

President and Chief

Executive Officer

•

38 years of oil and gas industry experience.

•

BSBA Wayne State University, 1971.

•

Originally an audit manager with Arthur Anderson in Detroit.

•

Formed Energy Resource Associates, Inc. in 1984, which acquired oil and gas properties and

controlling interests in limited partnerships.

•

In

1992,

properties

and

partnership

interests

were

exchanged

for

common

shares

of

Hampton

Resources

Corporation

(NASDAQ:”HPTR”),

which

Mr.

Lodzinski

joined

as

President.

•

Successfully

led

Hampton,

Texoil

(NASDAQ:

“TXLI”),

AROC

and

Southern

Bay

before

merging Southern Bay with GeoResources.

Robert J. Anderson

Vice President,

Business

Development –

Acquisitions and

Divestitures

•

23 years of diversified domestic and international oil and gas industry experience.

•

Petroleum engineering degree from University of Wyoming, 1986.

•

MBA, University of Denver, 1988.

•

Significant experience with  both major oil companies (ARCO International / Vastar

Resources) and independent oil companies (Hunt Oil / Hugoton Energy / Anadarko

Petroleum).

•

Employed by Anadarko Petroleum Corporation from October 2000 to February 2004 as a

petroleum engineer with increasing levels of responsibility.

•

Joined AROC in 2004 and has since been with Frank Lodzinski.

Collis P. Chandler, III

Executive Vice

President and

Chief Operating

Officer –

Northern

Region

•

17 years of oil and gas industry experience.

•

B.S. University of Colorado, 1992.

•

Former President and sole owner of Chandler Energy, LLC which conducted exploration and

production

operations

primarily

in

the

Rocky

Mountain

Region

and

Michigan.

Refer

to

Company

webpage

at

www.georesourcesinc.com

for

additional

information

8

Management Profiles (cont.)

Name

Title

Experience

Howard E. Ehler

Chief Financial

Officer and

Principal Accounting

Officer

•

43 years of oil and gas industry experience.

•

Accounting degree from Texas Tech, 1966.

•

Former partner with Grant Thornton.

•

Served

as

VP

of

Finance

and

CFO

for

Midland

Resources,

Inc.

from

March

1997

through

October 1998.

•

Employed as VP and CFO of AROC, Inc. from May 2001 through December 2004.

•

Employed by Southern Bay Energy, LLC since January 2005 as VP and CFO.

Francis M. Mury

Executive Vice

President and

Chief Operating

Officer –

Southern

Region

•

35 years of oil and gas industry experience.

•

B.S. Nichols State University, 1974.

•

Worked for Texaco and independents from 1974-1989 as a petroleum engineer.

•

Worked with Frank Lodzinski

for last 20 years.

9

Net Asset Value

Net Asset Value

(1)

PV-10 value based on strip pricing as of September 30, 2009.

(2)

As of September 30, 2009, excludes derivative financial instruments.

(3)

Williston Basin Bakken

acreage and Eagle Ford and Georgetown rights below Austin Chalk, at cost.

(4)

Estimate as of September 30, 2009.

($ in millions)

Total w/Partnerships

PV-10

(1)

% of Total

PV-10

% of Total

Proved Reserves:

Proved Developed Producing

$249.3

63.5%

$271.9

64.9%

Proved Developed Non-Producing

60.9

15.5%

63.0

15.0%

Proved Undeveloped

82.3

21.0%

84.2

20.1%

Total Proved PV-10 Value

$392.5

100.0%

$419.1

100.0%

Plus:  Working Capital

(2)

11.0

11.0

Acreage and Other

(3)

10.0

10.0

Less:   Total Debt

(4)

(104.0)

(104.0)

Total Net Asset Value

$309.5

$336.1

Shares Outstanding

(Thousands)

16,241

16,241

Net Asset Value Per Share

$19.06

$20.69

Direct Ownership

10

Proved

and

Potential

Reserves

(1)

Oil

Gas

Total

Corporate

Interests

MMBO

BCF

MMBOE

% of Total

PV 10 ($MM)

PDP

7.2

39.0

13.7

61.1%

$249.3

PDNP

1.9

5.7

2.8

12.5%

60.9

PUD

2.6

20.2

5.9

26.4%

82.3

Total

11.7

64.9

22.5

100.0%

$392.5

Oil

Gas

Total

Corporate

and

Partnership

Interests

(2)

MMBO

BCF

MMBOE

% of Total

PV-10 ($MM)

Proved

PDP

7.3

46.8

15.0

62.8%

$271.9

PDNP

1.9

7.2

3.0

12.4%

62.9

PUD

2.6

21.5

6.2

24.8%

84.2

Total Proved

11.8

75.5

24.2

100.0%

$419.1

Non-Proved

(see

following

slides)

(3)

6.4

23.6

10.3

Total

18.2

99.1

34.5

(1)

Proved reserves, as shown throughout this profile, are estimated as of 10/1/09 and based on NYMEX strip pricing at 9/30/09. The NYMEX oil strip used for the

estimates ranged from $70.65 per Bbl for 2009 to $90.16 per Bbl for years 2017 and beyond. The NYMEX gas strip ranged from $4.83 per Mcf for 2009 to $7.52 per

Mcf for years 2017 and beyond.

(2)

Partnership reserves do not include potential reversionary interests.

(3)

Represents non-proved reserve potential associated with existing fields or prospects that are scheduled and reasonably expected to be drilled with the Company’s

anticipated cash flows and current budget. Does not include certain projects which may result in additional prospects or drilling locations. Cautionary Note: The

Company is using the term “non-proved potential” in this profile to provide interested parties with estimates of reserve potential associated with certain projects. See

further information following in this profile. Such estimates are prepared by the Company, in accordance with reasonable industry practices. However, such estimates

are inherently imprecise and subject to material revisions.  As of September 2009, the SEC did not permit the disclosure of any non-proved  reserve estimates in SEC

filings. Accordingly, interested parties are urged to read the Company’s Annual Report on Form 10-K/A and its other SEC filings.      

11

Partnership Operations

SBE Partners LP

Catena Oil & Gas, LLC

General Partner

OKLA Energy Partners LP

2% GP Interest

30% GP Interest

Catena Oil & Gas, LLC.

Wholly owned subsidiary.

GE Capital = Sole Limited Partner.

30% interest in SBE partners acquired with

recent acquisition.

2% General Partner interest in OKLA Energy 

with 34% reversionary interest.

1.9 MMBOE  excluding reversionary

interests.

Partnerships generate fees, net income and

cash -

estimated for 2009 as follows:

Management fees -

$1.1 million

Partnership net income -

$4.6 million

Cash distributions -

$2.8 million

12

Proved

Reserves

(MMBOE)

(2)

Average Daily Production (Boe/d)

Reserves and production –

Direct interests

(1)

Proved

Reserves

–

22.5

MMBoe

(2)

(1)

Excludes partnership interests.

(2)

2006 –

2008 proved reserves based on SEC prices.  Reserves as of 10/1/09 based on 9/30/09 NYMEX strip prices.

768

1,826

3,388

5,054

250

750

1,250

1,750

2,250

2,750

3,250

3,750

4,250

4,750

5,250

2006

2007

2008

Current (Oct. '09)

2.4

15.7

14.6

22.5

0.0

5.0

10.0

15.0

20.0

25.0

2006

2007

2008

2009E

13

Production Growth –

Direct Interests

(1)

Annual Gas Production (MMCF)

Annual Oil Production (MBO)

Summary of acquisitions and divestitures:

April 2007: Reverse merger and Chandler

acquisition.

October 2007: $100.0 million acquisition primarily

in Louisiana and Texas.

January 2008: $6.6 million sale –

Michigan.

February 2008: $7.9 million acquisition –

Williston

Basin.

February 2008: $1.8 million sale –

Louisiana.

May 2008: $11.8 million sale –

seven fields,

Louisiana and Texas.

May 2008: Participation in the $61.7 million

formation of OKLA Energy Partners LP.

September 2008: $3.6 million acquisition –

Oklahoma.

2008 acquisitions and divestitures, high-graded

portfolio and expanded drilling inventory.

January 2009: $1.6 million sale –

Louisiana.

May 2009: $10.4 million acquisition –

Williston

Basin.

May 2009: $48.4 million acquisition –

Giddings

Field, Texas.

2009 acquisitions expand in core areas, high-

graded portfolio and expands drilling inventory.

(1)

Excludes partnership interests.  Based on PDP volumes and includes acquisitions closed in May.

184

392

743

753

0

200

400

600

800

2006

2007

2008

2009E

577

1,648

2,962

4,573

0

1,000

2,000

3,000

4,000

5,000

2006

2007

2008

2009E

Financial Summary

14

Selected Balance Sheet Data

(1)

The above table does not include the balance sheet effects of hedge accounting for derivative financial instruments which is required for financial statements

presented in accordance with generally accepted accounting principles. See the Company’s SEC filings for further information.

(in millions)

30-Jun-09

Dec. 31, 2008

Dec. 31, 2007

Cash

7.7

$                

14.0

$             

24.4

$             

Other

Working

Capital

-

Net

(1)

4.0

$                

(8.7)

$              

(10.5)

$            

Total

Working

Capital

(1)

11.7

$             

5.3

$                

13.9

$             

Oil & Gas Assets (Successful Efforts)

241.9

$           

181.6

$           

181.4

$           

Equity in Partnerships

3.4

$                

3.3

$                

1.8

$                

Long-Term Debt

98.0

$             

40.0

$             

96.0

$             

Common Stock and Additional Paid in Capital

113.3

$           

112.7

$           

79.8

$             

Retained Earnings

25.0

$             

21.0

$             

7.5

$                

Common Stock Outstanding

16.2

Financial Summary

15

($ in millions, except per share data and unit metrics)

YTD 06/30/09

2nd Qtr 2009

2008

2007

Key Data:

Avg. realized oil price ($/Bbl)

56.87

$       

59.28

$        

82.42

$       

67.20

$       

Avg. realized natural gas price ($/mcf)

3.95

$         

3.89

$          

8.12

$         

6.19

$         

Oil production (MBbls)

389

212

743

392

Natural gas production (MMcf)

1,752

1,087

2,962

1,648

Total revenue

33.8

$         

19.3

$          

94.6

$         

40.1

$         

Net income before tax

6.6

$           

5.7

$            

21.3

$         

8.0

$           

Net income

4.0

$           

3.5

$            

13.5

$         

3.1

$           

Net income per share (basic)

0.24

$         

0.22

$          

0.87

$         

0.25

$         

EBITDAX

(1)

18.2

$         

12.0

$          

53.0

$         

17.5

$         

EBITDAX per share (basic)

(1)

1.12

$         

0.73

$          

3.40

$         

1.42

$         

Historical Operating  Data

(1)

EBITDAX is defined as earnings before interest, income taxes, depreciation, depletion and amortization, impairments and exploration expense.  EBITDAX should

not be considered as an alternative to net income or cash flow as indications of performance or liquidity. See the Company’s SEC filings for further information.

16

Financial Summary

Historical Production Data

Historical Field-Level Operating Netback Data

YTD 06/30/09

2nd Qtr 2009

2008

2007

($ per BOE)

Revenue

$49.67

$48.99

$76.50

$60.17

Less:

LOE

$12.93

$11.23

$18.53

$16.23

G&A

5.91

4.91

5.80

9.77

Other Field Level Opex

(1)

3.90

2.25

8.92

7.46

Total Field Level Operating Costs

$22.75

$18.39

$33.25

$33.45

Field Level Operating Netback

$26.93

$30.60

$43.25

$26.72

(1)

Represents

severance

tax

expense

and

Re-engineering

and

workover

expense.

YTD 06/30/09

2nd Qtr 2009

2008

2007

Oil Production (MBbls)

389

212

743

392

Gas Production (MMcf)

1,752

1,087

2,962

1,648

Total Production (Mboe)

681

393

1,237

667

Avg. Daily Production (Boe/d)

3,732

4,309

3,388

1,826

17

(1)

EBITDAX is defined as earnings before interest, income taxes, depreciation, depletion and amortization, impairments and exploration expense.  EBITDAX should not

be considered as an alternative to net income or cash flow as indications of performance or liquidity. See the Company’s SEC filings for further information

EBITDAX

(1)

Total Leverage

($ in millions)

•

Clear track record of EBITDAX growth.

•

Conservative use of leverage to maintain strong balance sheet.

–

As of June 30, 2009, the Company’s total debt to Last Twelve Months (“LTM”)  EBITDAX is 2.3x.

–

$100 million borrowing base, Libor plus 2.25 –

3.00%.

–

Increased borrowing base to $135 million and added one bank to lending group in July, 2009.

–

Credit facility lead by Wells Fargo.

Strong Financial Position

18

Hedging Strategy

Oil Hedges

•

GEOI uses commodity price risk management in order to execute its

business plan throughout commodity price cycles.

•

2009 –

2010 natural gas hedges include hedge volumes intended to cover

GEOI’s share of partnership production.  Hedged volumes shown below are

about 51% of combined production volumes.

Natural Gas Hedges

Swap

Fixed Contract

Swap

Collar

0%

20%

40%

60%

80%

100%

2009E

2010E

2011E

$76.00

$74.71

$74.37

$43.85

$43.85

0%

20%

40%

60%

80%

100%

2009E

2010E

2011E

$5.08

$5.12

$7.00 - $10.75

$7.00 - $9.90

$7.00 - $9.20

Regional Overview

20

Southern Region

TX

NM

LA

Loco Hills

Maljamar

Harris

M.A.K.

Warwink

Wheeler

Chittim Ranch

Giddings*

*SBE Partners LP properties

Odem

Driscoll

Oak Hill

Golden

Meadow

Quarantine

Bay

Eloi Bay

St. Martinville

Frisco

OK

OKLA Energy Partners

LP properties

Accounts

for

73%

of

reserves

and

approximately

83% of total production.

•

High-impact exploration potential.

•

Development and recompletion potential.

Continuous successful Austin Chalk drilling

program.

•

Significant working interests plus partnership

interests.

•

Thirteen wells drilled with 100% success rate.

•

69 producing wells.

•

6-8 wells expected to be drilled in 2009 and in 2010.

•

Recent additional acreage acquisitions.

•

May deploy additional rig with cost reductions.

•

Yegua, Eagle Ford Shale and Georgetown

potential.

Two 3D seismic projects in progress.

21

Northern Region

ALBERTA

MANITOBA

SASKATCHEWAN

MT

SD

ND

Newporte

Sherman/Wayne

Landa

Starbuck

Comertown

Fairview/Mondak

Sioux Pass

Four Mile Creek

Patent Gate

Flat Top

Note: Highlighted area represents the Williston Basin.  

Bakken

JV

Accounts for 27% of reserves and approximately 17% of

total production.

North Dakota shallow:

•

Starbuck waterflood

initial installation early 2008, phase two

finished in early 2009.

o

Initial response realized.

•

SW Starbuck waterflood

installation completed early 2009.

•

Horizontal infill locations in other fields.

North Dakota Bakken:

•

Recent acquisitions in approximately 66,000 net acres.

•

Joint venture with 10-18% working interest in approximately

110,000 net acres.

•

Current  three rig program, expected to increase to four rigs in

1st quarter 2010.

•

30 joint venture operated wells drilled.

•

Acquired and/or participated in over 120 non-operated wells.

•

Joint venture expects to drill approximately 60 wells in the

next 18 months.

•

Initial production rates as high as 1400 bopd

on single lateral

640 acre units.

(1) Well counts exclude numerous wells with nominal interests.

22

Planned

projects

total

$153

million

and

are

diversified

across

GeoResources’

core

areas.

Expenditures to generally remain within cash flow.

Estimated $40 million in next 12 months.

Budget allocation favors low-risk, high cash flow projects.

Budget revisions will reflect  commodity prices and include recent acquisitions.

•

Flexibility between gas and oil projects.

•

Flexibility between development exploration.

Southern Region Capital Expenditures

Northern Region Capital Expenditures

$73 million total

$80 million total

Exploration &

Development Projects

23

Selected Upside Projects

Reserve Potential

Reserve Potential

Oil

Gas

Total

Field

State

MMBO

BCF

MMBOE

Bakken

Shale

(1)

ND,MT

2.3

1.0

2.4

Chittim

(2)

TX

-

1.1

0.2

Giddings

(3)

TX

-

14.8

2.5

Mak

TX

0.3

-

0.3

Oklahoma (various net)

(4)

OK

-

1.8

0.3

Quarantine Bay

(5)

LA

.7

4.9

1.5

St. Martinville

(6)

LA

1.5

-

1.5

SW Starbuck

ND

0.2

-

0.2

Starbuck

Waterflood

Unit

(7)

ND

1.4

-

1.4

Non-Proved Potential

6.4

23.6

10.3

_______________________________________________________________________________

(1)

Estimated participation in 100 wells pending continued favorable drilling results.  Does not include Three

Forks / Sanish potential.

(2)

Does not include Pearsall Shale.

(3)

Does not include Yegua, Eagle Ford Shale or Georgetown potential or proved undeveloped reserves.

(4)

Includes net interest in 6 non-proved locations.

(5)

Represents Company estimated base case (low) for one prospect area.  Excludes other prospects on

lease and all deep potential below 16,000 feet.

(6)

Includes six non-proved locations above 8,000 feet.  Seismic shoot may alter non-proved, sub-surface

locations and result in additional locations.

(7)

Engineering estimates for a successful flood range from 1.4 to 2.3 MMBO.

24

Bakken

Shale

Bakken

Shale

Note:  Yellow-highlighted areas represent the Company’s acreage position.

Working interests ranging from 10% to 18%

in 110,000 net acres.

63,000 acres in Mountrail County.

Three rigs running.

30 wells drilled. Joint venture expects to drill

60 wells in the next 18 months.

(1)

Initial

production

rates

up

to1,400

Bopd

per

well for single laterals on 640 acre spacing

units.

Developing on 640 acre units as well as

1,280 acre and larger units.

Additional upside in Three Forks and Bakken

increased density wells.

Detailed map on next slide

25

Bakken Shale

Note:  Yellow-highlighted areas represent the Company’s acreage position.

Van Hook Area

640 and 1,280 acre units being drilled.

Some larger units under the lake.

Multiple wells from single drilling pad.

Minimize facilities and roads.

Maximize infrastructure.

Developing reserves with difficult

access.

Minimize disturbance and the number

of locations.

26

Giddings Field

Austin Chalk Play

13 wells drilled  –

100%

success.

68,000 acres held by

production and leasehold. 

22 additional locations

GEOI owns ~ 37% -

53%  of

additional  locations. 

Additional upside includes:

•

Yegua, Eagle Ford shale and

Georgetown  potential.

•

Multiple wells with rate increase

potential from slick water fracture

stimulations.

27

Austin Chalk Acreage

Giddings Field

•

Giddings Field Austin

Chalk Acreage and

areas of currently

productive in chalk

28

Grimes and Montgomery Counties

Austin Chalk Development

•

Low Risk Horizontal

Wells

•

Last well: Longstreet 1H

produced 1.0 BCFG in 67

days

•

Single and multiple

laterals

•

Eastern Grimes / Western

Montgomery dry gas

•

Western Grimes gas  with

large volume of liquids

•

Single rig continuous

program

•

Tight gas –

severance 

tax exemption

Longstreet 1H

29

Eagle Ford Trend

South & Central Gulf Coast Texas

•

Significant acreage

position in trend

•

Eagle Ford shale

present over much

larger area than

apparent trend

•

Trend depicted where

Eagle Ford is +-7000’

to +-14000’

•

Early in development

30

South Texas Eagle Ford

Recent Activity Map

31

Central Texas Eagle Ford

Recent Activity Map

•

Apache active in our area.

•

Majority of Apache wells

vertical

•

Our Brazos, Burleson,

Fayette and Washington

Counties holdings currently

appear most prospective for

Eagle Ford

Quarantine Bay

Quarantine Bay Field

LA

New

Orleans

Black Bay

Breton Sound

Eloi

Bay

Lake Salvador

Lake Borgne

Lake Ponchartrain

Quarantine Bay

Violet

Westwego

Belle Chasse

Braithwaite

Pointe A La Hache

Port Sulphur

Quarantine Bay

Oil & Gas Field

New

Orleans

Black Bay

Breton Sound

Eloi

Bay

Lake Salvador

Lake Borgne

Lake Ponchartrain

Quarantine Bay

Violet

Westwego

Belle Chasse

Braithwaite

Pointe A La Hache

Port Sulphur

Quarantine Bay

Oil & Gas Field

GeoResources has a 7% working interest above

10,500 feet and a 33% working interest below

10,500 feet, in approximately 14,000 acres.

Cumulative Production = 180 Million Bbls and

285 BCF.

Shallow zone potential (<10,500 ft):

•

Numerous behind pipe opportunities due to

multiple stacked sand reservoirs.

•

Rate acceleration wells.

•

Pending prices and drilling cost

reductions.

Significant deep potential (>10,500 ft): 

Schlumberger reprocessed and interpreted

the 3-D seismic data.

Initial prospect.

•

Multiple objectives to 16,000 ft.

•

Deeper objectives.

32

33

Starbuck and SW Starbuck

Water-flood Units

Starbuck Unit

ND

HAAS

North Dakota

LANDA NE

LEONARD

ZION

LANDA

ROTH N

ROTH

SHERMAN

WAYNE

STARBUCK

CANADA

Bottineau County

T163N

T162N

T161N

R79W

R81W

R80W

R82W

R83W

HAAS

North Dakota

LANDA NE

LEONARD

ZION

LANDA

ROTH N

ROTH

SHERMAN

WAYNE

STARBUCK

CANADA

Bottineau County

T163N

T162N

T161N

R79W

R81W

R80W

R82W

R83W

Starbuck 6,618acres, 96% WI.

SW Starbuck 560 acres, 80% WI.

Starbuck phase one completed 2008.

•

Phase two and SW Starbuck expansion

completed 2009.

•

Recent initial response.  

Primary production totals 1.4 MMBO for the 

Starbuck Midale and Berentson Zones.

Primary production for SW Starbuck totals

162 MBO.

Approximately $6.0 million on waterflood

implementation.

The Company estimates additional reserves

of 1.6 –

2.5 MMBO for both projects.

34

Starbuck and SW Starbuck

Water-flood

35

Key Investment Highlights

Value Creation

Experienced Management and Technical Staff with  Large Ownership

•

Successful

Track

Record

of

Creating

Value

and

Liquidity

for

Investors

•

Board and Management Own 53%

Attractive Value Proposition

•

Trading at a Discount to NAV

Strong Asset Base

•

Strategically Located

•

Geographically Diverse

•

Balanced Oil vs. Gas

•

High Level of Operating Control

Significant Identified Upside Potential on Existing Properties

•

Low Risk Development Potential (i.e. Austin Chalk, Bakken)

•

Higher Impact Exploration Potential (i.e.  Eagle Ford, Georgetown)

Strong Financial Position; Moderate Leverage, Significant Cash Flow