investors presentation · 4 petrolifera petroleum limited overview • international oil and...

Investors PresentationWinter, 2008-2009

2

Forward Looking Information

This presentation contains forward-looking information, including but not limited to future exploration and development opportunities, future drilling plans, anticipated capital expenditures, planned farmout arrangements, forecast production, estimated results from Petrolifera’s waterflood and optimization program and estimates of reserves. Forward looking information is not based on historical facts but rather on Management expectations regarding the Corporation’s future growth, results of operations, production, future capital and other expenditures (including the amount, nature and sources of funding thereof), competitive advantages, plans for and results of drilling activity, environmental matters, business prospects and opportunities. Such forward looking information reflects Management’s current beliefs and assumptions and are based on information currently available to Management. Forward looking information involves significant known and unknown risks and uncertainties. A number of factors could cause actual results to differ materially from the results discussed in the forward looking information including, but not limited to, risks associated with the oil and gas industry (e.g. operational risks in development, exploration and production, delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections in relation to production, costs and expenses and health, safety and environmental risks), the risk of commodity price and foreign exchange rate fluctuations, the uncertainty associated with negotiating with foreign governments and third parties located in foreign jurisdictions and the risk associated with international activity. Additional risks and uncertainties are described in the Corporation’s Annual Information Form which is filed on SEDAR at www.sedar.com. The reserves in this presentation represent estimates only. The reserves from the company’s properties have been independently evaluated by GLJ Petroleum Consultants (“GLJ”). This evaluation includes a number of assumptions relating to factors such as initial production rates, production decline rates, ultimate recovery of reserves, timing and amount of capital expenditures, marketability of production, future prices of crude oil and natural gas, operating costs, well abandonment and salvage values, royalties and other government levies that may be imposed during the producing life of the reserves. These assumptions were based on price forecasts in use at December 31, 2007 and many of these assumptions are subject to change and are beyond the control of the company. Actual production, sales and cash flows derived therefrom will vary from the evaluation and such variations could be material. Reference is made to the company’s Annual Information Form for a detailed description of the assumptions utilized in the reserves report prepared by GLJ.

Forecast capital expenditures are based on Petrolifera’s current budgets and development plans which are subject to change based on commodity prices, market conditions, drilling success, potential timing delays and access to cash, cash flow, available credit and third party participation. Petrolifera’s capital budget has been prepared based upon anticipated costs for equipment and services which are subject to fluctuation based upon market conditions, availability and potential changes or delays in capital expenditures.

3

Forward Looking Information Continued

Additionally, forecast capital expenditures do not include capital required to pursue future acquisitions. Anticipated production growth has been estimated based on (i) the proposed drilling program with a success rate based upon historical drilling success and an evaluation of the particular wells to be drilled and has been risked, (ii) current production and anticipated decline rates and (iii) the projected impact of the company’s waterflood program. Production is dependent on sustained productivity of new and existing wells and the results of Petrolifera's water flood and water injection program. Although the forward looking information contained herein is based upon assumptions which Management believes to be reasonable, the Corporation cannot assure investors that actual results will be consistent with this forward looking information. This forward looking information is made as of the date hereof and the Corporation assumes no obligation to update or revise them to reflect new events or circumstances, except as required by law. Because of the risks, uncertainties and assumptions inherent in forward looking statements, prospective investors in the Corporation’s securities should not place undue reliance on these forward looking statements. A barrel of oil equivalent (boe) is derived by converting gas to oil in the ratio of six thousand cubic feet of gas to one barrel of oil and may be misleading, particularly if used in isolation. A boeconversion is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.

Cash flow does not have a standardized meaning prescribed by Canadian Generally Accepted Accounting Principles (“GAAP”) and therefore may not be comparable to similar measures used by other companies. Cash flow includes all cash flow from operating activities and is calculated before changes in non-cash working capital. The most comparable measure calculated in accordance with GAAP would be net earnings. Cash flow is reconciled with net earnings on the Consolidated Statement of Cash Flows in the company’s audited annual financial statements and below. Management uses these non-GAAP measurements for its own performance measures and to provide its shareholders and investors with a measurements of the company's efficiency and its ability to fund a portion of its future growth expenditures.

Quarter Ended Sep. 30, 2008 June 30, 2008 Mar. 31, 2008 Dec. 31, 2007

(in $000’s)Net earnings for the period $3,564 $3,590 $1,738 $4,863Add (deduct)

Stock-based compensation 1,123 731 2,398 1,414Depletion, depreciation and accretion 6,599 6,388 4,669 4,470Future income tax provision (recovery) 2,573 (538) 1,325 534Foreign exchange loss (gain) (239) 1,118 90 (3,956)Fair value impairment – ABCP 1,885 2,002 1,490 3,382Amortization of deferred charges 221 194 192 -

Cash flow $15,726 $13,485 $11,902 $10,707

4

Petrolifera Petroleum Limited Overview

• International oil and natural gas exploration and production company

• Listed on TSX – PDP– Recent price C$1.53– 52 week trading range C$1.20 – C$12.95

• Average volume ~125,000 shares per day

• Market capitalization ~$85 mm – Enterprise value ~$130 mm

• Shares outstanding: 54.9 mm (basic), 58.7 mm (fully diluted)

• Connacher Oil and Gas – founding shareholder and largest current shareholder with approximately 24% ownership

5

Petrolifera Petroleum Limited 2009 Budget Highlights

• Stable Production

• Excellent liquidity maintained

• Farmouts under discussion allow anticipated leveraged program to $84 million program (1)

• PDP’s direct share only $30 million

• No anticipated equity financing in 2009(1)

(1) Refer to slide 2 for Forward Looking Information

6

Petrolifera Recent Quarterly Results

(1) Cash flow does not have a standardized meaning prescribed by GAAP. Refer to slide 3 for a reconciliation to net earnings, a GAAP measure. See slide 2 for Forward Looking Information

Third Quarter2008

Second Quarter 2008

First Quarter 2008

Fourth Quarter 2007

Daily Sales Volumes

6,850

5,363

7,744

$32,126

$15,726

$0.29

$3,564

$0.06

$21,046

7,111

5,922

8,098

$33,622

$13,485

$0.27

$3,590

$0.07

Natural Gas – mcf/d 7,044 2,860

$29,110

Cash flow(1) ($000) $11,902 $10,707

Per share – basic ($/share) $0.24 $0.21

Barrels of oil equivalent –boe/d

7,900 7,042

Total Revenue ($000) $27,167

Crude Oil – bbl/d 6,726 6,565

$27,266

Net Earnings ($000) $1,738 $4,863

Per share – basic ($/share) $0.04 $0.10

Capital Expenditures ($000) $31,056 $57,608

7

Petrolifera Sales Volumes (boe/d)

2005 2006 2007 2008 YTD Q3

Natural GasCrude Oil & NGLs

7,9138,279

6,171

360

8Data Sources: IHS, BU’s’ Wood Mackenzie, Published Data

(News Services); as of January 2008

PETROLIFE

RA

PETROLIFE

RA

PETROLIFE

RA

PETROLIFE

RA

PETROLIFE

RA

PETROLIFE

RA

Countries with Favorable Host Country PoliciesCountries With Unfavorable Host Country Policies

Discovered Resource in Latin America by Exploration Well and Country, Last 25 Years

Petrolifera – Countries of Operations

9 Data Sources: IHS, BU’s, Wood Mackenzie, Published Data (News Services); as of January 2008

Discovered Resource in Latin America by Exploration Well and Basin, Last 25 Years

PETROLIFE

RA

PETROLIFE

RA

PETROLIFE

RA

PETROLIFE

RA

PETROLIFE

RA

PETROLIFE

RA

Countries with Favorable Host Country PoliciesCountries With Unfavorable Host Country Policies

Petrolifera – Basins of Operations

10

Argentina Neuquen BasinDrilling and Geophysical Programs 2008(1)

Puesto Morales

Puesto Morales E

Rinconada (N & S)

Gobernador Ayala II

Vaca Mahuida

Puesto Guevara

Puesto Morales2008 (To Q/4) – 25 wells, No seismic

17 Oil, 4 Inj, 1 Dual Inj & Oil,1 Gas, 2 dry

2008 (Q/4) – 1 oil well, No seismic

Rinconada2008 (To Q/4) – 2 wells, No seismic

1 Oil, 1 Dry2008 (Q/4) – 1 well (WOC), No seismic

Vaca Mahuida (50% costs)2008 (To Q/4) – 3 wells, 1150km2 3D seismic

1 Oil, 1 Dry, 1 WOC.2008 (Q/4) – No wells, finished 3D processing

Gob. Ayala II 2008 (To Q/4) – No wells, process 210 Km2 3D2008 (Q/4) – No wells, No seismic

Puesto Guevara 2008 (To Q/4) – No wells, 100km2 3D seismic2008 (Q/4) – No wells, finished 3D processing

Puesto Morales Este2008 (To Q/4) – 2 wells, No seismic

1 Oil, 1 Gas2008 (Q/4) – No wells, No seismic


11

Argentina Neuquen BasinDrilling and Geophysical Programs 2009 (1)

Puesto Morales

Puesto Morales E

Rinconada (N & S)

Gobernador Ayala II

Vaca Mahuida

Puesto Guevara

Puesto Morales2009 – 1 well, No seismic

Rinconada2009 – No wells, No seismic

Vaca Mahuida (50% costs)2009 – 8 wells, No seismic

Gob. Ayala II 2009 – 4 wells, No seismic

Puesto Guevara 2009 – No wells, No seismic

Puesto Morales Este2009 – No wells, No seismic

12

SecondaryFault

Offset VSP

PMN.a-1052 PMN.x-1082

SB

Catriel

LM2

3D Survey

OilWater

140° Dipingazimut

Puesto Morales – 1082 and 1052 Wells

6 meters of SB payLow and wet

• Deviated well PMN x-1082 drilled under lake

• Current production 250 bo/d• Shallow water seismic needs to be

shot to investigate extension and other structures

Sierras Blancas (SB)

13

• PME x1002 found 7m of good reservoir with 42 API oil (no associated gas) in LM2 layer

• Potential for new wells• Risk of reservoir

heterogeneity

• Oil production from upper Loma Montosa in other wells as PMN 1002, PMN 1040, PMN 1070, PMN 1046

Puesto Morales Este – 1002 LM2 Oil Well

To PMN 1002& PMN 1040

PMS 1022

PME 1002

NW SE

14

• End of year oil production(1)

• 62% Base• 18% Waterflooding• 17% New 2008 Development wells• 5% Exploratory

• End of year gas production(1)

• 70% non-associated gas from LM• 30% associated gas

Argentina – 2008 Production Performance

Puesto Morales + Rinconada

0

2.000

4.000

6.000

8.000

10.000

12.000

14.000

Ene

-06

Feb-

06

Mar

-06

Abr

-06

May

-06

Jun-

06

Jul-0

6

Ago

-06

Sep

-06

Oct

-06

Nov

-06

Dic

-06

Ene

-07

Feb-

07

Mar

-07

Abr

-07

May

-07

Jun-

07

Jul-0

7

Ago

-07

Sep

-07

Oct

-07

Nov

-07

Dic

-07

Ene

-08

Feb-

08

Mar

-08

Abr

-08

May

-08

Jun-

08

Jul-0

8

Ago

-08

Sep

-08

Oct

-08

Nov

-08

Dic

-08

bbl/d

Water Flooding

2008 Drilling Campaign (27 wells)




PMS

2008 Oil Production

0

1000

2000

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6000

7000

8000

9000

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ary

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uary

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ch

April

May

June

July

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st

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embe

r

Oct

ober

Nov

embe

r

Dec

embe

r

Bop

d

Exploration

New Dev Wells 2008

Waterf looding

Basic Primary Production


15

• Injection in SB/PR in North and Center Pools

• Injection pilot in LM9 in North Pool

• Injection pilot in LM10 in PMS field

• 17 total injectors

• Water injection rate reached facility capacity of 25,000 bw/d

• Current production from waterflooding, 783 bo/d

Puesto Morales – Current Waterflood Projects

LM9 Waterflooding

pilot

LM10 Waterflooding

pilot

SB&PR area ofWaterflooding

influence

16

Puesto Morales –Incremental Waterflood Production Forecast

Waterflooding Production

0

200

400

600

800

1000

1200

1400Ja

nuar

y

Febr

uary

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ch

April

May

June July

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st

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embe

r

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ober

Nov

embe

r

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embe

r

2008

Wat

erflo

ding

oil

prod

uctio

n (b

opd)

Current WF productionJuly WF production forecast

(1)

(1)


17

• Optimize Waterflood by increasing liquid production• Replace pump jacks with ESP’s

• Introduce Injector to Producer tracers in order to optimize volumetric sweep efficiencies

• Build a whole-field dynamic simulation model (Center + North)

• Evaluate the economics of drilling more wells to optimize recovery

Puesto Morales – SB & PR Oil Recovery Optimization(1)


18

GOC

GAS ZONE

OIL ZONE

GOC

GAS ZONE

OIL ZONE

Depth 1400 mbgl

Net Pay 2 – 3 meter

1 – 10 mD

18% – 25%

Permeability

Porosity

PUESTO MORALES NORTE (LM9)• Primary Recovery Factor ~ 10 to

15%

PUESTO MORALES SUR (LM10)• Production flat at 80bopd over the

last 30 years• 2007 Oil Reserve P1 @ 0.29

MMbo(1)

• Current Recovery Factor of 8-10%

GENERAL• Two waterflood pilot projects

implemented (one in north for LM9, one in south for LM10)

• With an increased recovery factor through the implementation of a waterflood and a reduction of well costs – aggressive development becomes attractive

Puesto Morales – LM Development

PUESTO MORALES NORTE (LM9)NET PAY MAP

Pilot WF Injector

(1) Based on the independent reserves evaluation prepared by GLJ Petroleum Consultants Ltd. As at December 31, 2007. The estimates of reserves for an individual property may not reflect the same confidence level as estimates of reserves for all properties due to the effects of aggregation.

19

Sierra Nevada & Magdalena Blocks

Major Structural Elements

500 km

Llanos Basin

Barinas-Apure Basin

GuayanaShield

Putumayo Basin

OrienteBasin

Marañon Basin

Panama Arc LMV

MMV

UMV

Caribbean PlateSouthern Caribbean Accretionary Prism

Nazca Plate

Cusiana-Cupiagua

Brasil

Venezuela

Perú

Ecuador

Eastern Cordillera

Central Cordillera

Colombia – Sierra Nevada & Magdalena Blocks

20

Colombia – Sierra Nevada & Magdalena Blocks

Plato Sub-basin

San Jorge Sub-basin

Sinu Sub-basin

La Creciente(600 BCF) El Dificil

(350 BCF)

Caribbean Basin

Chimichagua(300 BCF)

Sierra Nevada & Magdalena

Hydrocarbon Charge

El Dificil

Chimichagua

21

La Pinta

Dificil

Brillante

PROSPECTS(1)

•La Pinta -Turbidite Sdst• Size P10 – 32.2 Km2

P90 – 9.8 Km2

•Brillante –Deltaic Sdst• Size P10 – 40.0 Km2

P90 – 5.0 Km2

•Dificil – Limestone Reef• Size P10 – 18.0 Km2

P90 – 4.5 Km2

Colombia – Sierra Nevada

Legend

P10P90Amplitude Anomaly

(1) Reference is made to Petrolifera’s Annual Information Form for the year ended December 31, 2007 (“Business of the Corporation – Principal Properties” and “Risk Factors”) for a detailed description of Petrolifera’s interest in the license, the location of the license, product types reasonable expected and risks and uncertainties relating to international exploration activities.

22

TD=13,000’

• Location is located 600 meters from the Guamito-1 well drilled in 1975 by Chevron

• Upper interval tested 120 bbl/d and 500 mcf/d• Lower interval tested 410 bbl/d 46.7º API

BSW=50% (low salinities of water would indicate it to be filtrate)

• A production test was not possible because they were unable to transport produced oil

• In 1983, Ecopetrol attempted a production test but casing problems resulted in the well being P&A’d

Colombia – Sierra Nevada La Pinta Prospect

23

Not tested

TEST: 410 BOPD 46.7º API, BSW 50% 8,700 ppm Cl(filtrate)

Not tested

31’ openedTEST: 120 BOPD 47.7ºAPI, 500 MCFPD

153’ openedNot tested

Potential oil-bearing SS

6800’

8800’

8400’

8700’

6900’

Structural map seismic horizon

10600’

10500’

10300’

10400’

Sierra Nevada – Guamito Well Log

24

Two 3D seismic program to be shot (pink hatched areas)• Northern program to define San Angel structure and evaluated San Angel #1 gas discovery

made in the 1940’s and to define Oligocene reefs analogous to the El Dificil Field • Southern program to define the southern extension of the Chimichagua gas pool

Colombia – Magdalena

Relinquished portion of Sierra Nevada II BlockRelinquished portion of Sierra Nevada II Block

Magdalena BlockMagdalena Block

Sierra Nevada BlockSierra Nevada Block

El Dificil FieldEl Dificil Field

Chimichagua FieldChimichagua Field

San Angel #1 Gas Discovery (D&A’s not drilled deep enough)

San Angel #1 Gas Discovery (D&A’s not drilled deep enough)

25

Turpial Block

Major Structural Elements

Colombia – Turpial Block

500 km

Llanos Basin

Barinas-Apure Basin

Guayana Shield

Putumayo Basin

Oriente Basin

Marañon Basin

Panama Arc LMV

MMV

UMV


Nazca Plate

Cusiana-Cupiagua

Brasil

Venezuela

Perú

Ecuador

Eastern Cordillera

Central Cordillera

500 km

Llanos Basin

Barinas-Apure Basin

Guayana Shield

Putumayo Basin

Oriente Basin

Marañon Basin

Panama Arc LMV

MMV

UMV


Nazca Plate

Cusiana-Cupiagua

Brasil

Venezuela

Perú

Ecuador

Eastern Cordillera

Central Cordillera

260 5 Km

Chorro Gr.

ColoradoTune/Real

ChorroSeeps

AA AA’’

Seeps

Lower Cretaceous

Lower Cretaceous

Dos Hermanos FaultGirón

La Luna

La Luna

Velásquez Fault

WestWest EastEast

Eastern Cordillera

Zorro

Turpial Block

MugrosaCáceres FaultAgata Fault

La Salina FaultOil

Cocorná Field(heavy crude)

GuaduasCentral CordilleraVelásquez Platform

(Basement)

Petróleo

Turpial Block – Idealized Cross-section, Middle Magdalena Basin

Rio Horta Block

Orquídea Block

Cocorná Field

Velásquez Field

Cross-section A-A’

Turpial Block

Velásquez Field(medium crude)

27

-pCm

Ti

QalpCm

Om

Q

QTs

QalRTKi TPi

Om-

Cocorná ‐Jazmín

Velásquez

Palagua

30 km

Sistema de Fallas Sistema de Fallas PalestinaPalestina Falla Falla

VelVeláásquezsquez

Cordillera Central

Cordillera Oriental

Plat. Vel..

Graben Bronce

Falla BronceFalla Bronce

PaleocenoPaleoceno‐‐RecienteRecienteCompresionCompresion//TranspresionTranspresion NONO

CretCretáácicocicoCompresionCompresion SESE

PaleocenoPaleoceno‐‐RecienteRecienteTranstensionTranstension NENE

PaleocenoPaleoceno‐‐RecienteRecienteHundamientoHundamiento ““ForelandForeland””

Falla Falla CocornCocornáá

Colombia – Turpial Tectonic Framework

28

Planned 3DSeismic Program

TURPIAL BLOCK

• 3D seismic program 120 km2

began in late October 2008

• 2D seismic program to infill where 3D not practical will begin upon completion of 3D program

• Drilling anticipated for 2nd half of 2009

Colombia – Turpial Seismic Program(1)

Planned 2DSeismic Program


29

Peru – Petrolifera's Land Position

MARANON BASIN

Block 106 - 1,998,000 acres

UCAYALI BASIN

Block 107 - 3,205,000 acres

Block 133 - 978,659 acres(awaiting presidential decree)

Repsol discovery

Camisea

Repsol/Advantage heavy oil

discoveries

30

Regional Petroleum Systems, Peru & Ecuador

PerPerúú

Paleozoic OilsPaleozoic Oils

Pacific OceanPacific Ocean

ColombiaColombia

CamiseaCamisea

EcuadorEcuador Cretaceous OilsCretaceous Oils

BrazilBrazil

Marañon Basin

Triassic/Jurassic OilsTriassic/Jurassic Oils

Madre De Dios Basin

OrienteBasin

Talara Basin

Guayaquil Basin

Titicaca Basin

Source: Geomark, Perupetro

• Four world-class and regionally extensive petroleum systems: Cretaceous “La Luna”(Chonta-Napo), Triassic-Jurassic Pucará(Aramachay), Carboniferous-Devonian (Ambo-Cabanillas), Permian (Ene)

• Block 107 oil seeps typed to Ene w/some Cretaceous input; 34o API oil at the surface just west of Block 133 (volatile oil or retrograde condensate at reservoir conditions); gas seeps under analysisUcayali Basin

Río Pichis gas seepQuimiari oil seep

Oil and Gas Seeps(photos)

133133

107107

106106

31

Maranon Basin – Block 106(1)

PROSPECTS

• San Juan• Offsetting San Juan Well which tested oil

• San Juan E• San Juan S

LEADS

• San Juan N• Corrientes NE

• Possible mirror image of Corrientes Field• Cuinico N

• Well believed to be drilled off structure• Cuinico S

• Well tested 18.8o API oil and, and is believed to be drilled off structure

• Diana Mae• Well tested (RFT) 29.9o oil from two different

sands, and is believed to be drilled off structure• Concordia

• Structure very poorly defined if at all present• Well head leaking oil• NW-SE trending series of gas seeps near old well

Oil PipelineOil Pipeline

San JuanSan Juan

San Juan NSan Juan N

San Juan SSan Juan S

Corrientes NECorrientes NE

Cuinico NCuinico N

Cuinico SCuinico SDiana MaeDiana Mae

ConcordiaConcordia

AericoAerico

San Juan ESan Juan E

(1) Reference is made to Petrolifera’s Annual Information Form for the year ended December 31, 2007 (“Business of the Corporation – Principal Properties” and “Risk Factors”) for a detailed description of Petrolifera’s interest in the license, the location of the license, product types reasonably expected and risks and uncertainties relating to international exploration activities.

32

Ucayali Basin Blocks 107 and 133(1)

Block107

Block133

New seismic acquired by Petrolifera (950 Km)

Existing seismic

Block 133

Block 107

(1) Reference is made to Petrolifera’s Annual Information Form for the year ended December 31, 2007 and the Prospectus dated October 17, 2005 for a detailed description of Petrolifera’s interest in Block 107 and further details on the location, product type reasonably expected and risks and uncertainties

33

0 10 20 30 40

Km

Block 107 Prospects and Leads

PROSPECTS

• Cretaceous reservoirs in foreland closure (A-)

• Subsalt Paleozoic play (B)

LEADS

• Shallow Cretaceous structure playing off of 200 meters of gas column in Oxapampa well (B)

• Subthrust play – probably 3 separate structures (B-)

• Cretaceous reservoirs in forland structures yet to close (C)

• Large structures in along mountain front yet to be delineated (C+)

SEEPS

Oil

Gas

FlameableGas Seep Block 133Block 133

Block 107Block 107

34o API Oil SeepPaleozoic & Cret

Source Rocks

34o Oil Seep in water wells

Paleozoic & CretSource Rocks

(1) Reference is made to Petrolifera’s Annual Information Form for the year ended December 31, 2007 (“Business of the Corporation – Principal Properties” and “Risk Factors”) for a detailed description of Petrolifera’s interest in the license, the location of the license, product types reasonable expected and risks and uncertainties relating to international exploration activities.

34

B

B’

Block 107 – Examples of Sub-Salt Styled Prospects

Oxapampa 7-1

Oxapampa 7-2

Time Structure on Permian Blue Marker

Prospect A = 26 Km2

• The two wells, Oxapamapa 7-1 and Oxapampa 7-2, were not drilled deep enough to test the deeper prospective horizons

• Both were drilled on surface structures with no seismic

Prospect B = 36 Km2

35

San Matias Thrust Fault

Salt

Section outcrops along San Matias Mountains and contains oil stained sandstones

Mapped Horizon

Block 107 – Seismic Line Through Prospect B

B B’

36

• Stable production base in Argentina provides substantial yearly cash flow

• Exposure to low cost exploration potential through drilling on Vaca Mahuida and Gobernador Ayala II in 2009(1)

• Waterflood implemented at Puesto Morales showing positive results

• Two new pilot waterflood projects in the Loma Montosa Formation at Puesto Morales in Argentina, implemented

• High impact drilling to commence in late 2008 in Colombia and continues in 2009 and 2010(1)

• Petrolifera is poised for significant growth in 2009-2010• Good liquidity• High impact drilling• Strategic joint ventures under discussion• New opportunities being addressed

Petrolifera – Summary


Thank You

investors presentation · 4 petrolifera petroleum limited overview • international oil and...

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