caño rondon-1

Reservoir Fluid Study

for

OCCIDENTAL DE COLOMBIA

Caño Rondon-1 Well, Form.: Mirador / K2A1

RFL 0603116

Core LaboratoriesCra 39 Nro. 168-52, Bogotá, Colombia

Tel: +57 (1) 6740400 Fax: +57 (1) 6730060 Web: http://www.corelab.com

The analyses, opinions or interpretations in this report are based on observations and material suppliedby the client to whom, and for whose exclusive and confidential use, this report is made. Theinterpretations or opinions expressed represent the best judgement of Core Laboratories Venezuela,S.A. (all errors and omissions excepted); but Core Laboratories Venezuela, S.A. and its officers andemployees assume no responsibility and make no warranty or representations as to the productivity,proper operation or profitability of any oil, gas or any other mineral well formation in connection withwhich such report is used or relied upon.

Core LaboratoriesCra. 39 Nro. 168-52

Bogotá, ColombiaTel: 57 1 6740400

Web: http://www.corelab.com

Sincerely,CORE LABORATORIES VENEZUELA, S.A.

David McEvoyManagerReservoir Fluids Laboratory

October 16th, 2006

Occidental de Colombia.Bogota, Colombia.

Attention : Eng. Aldo Caliz Subject: Reservoir Fluid Study Well: Caño Rondon-1Formation: Mirador / K2A1Interval: 9,760'-10,378'File: 0603116

Dear Sirs.:

Two bottomhole samples and two wellhead samples from the subject well were collected onJuly 11th and July 12th of 2006 by Core Laboratories representatives and delivered to ourfluid laboratory in Bogotá for use in the performance of a Reservoir Fluid Study. Thesamples were transported to the laboratory whereupon sample validation and analysiscommenced.

Preliminary results were reported during the execution of the study and the final report ispresented in the following pages.

It has been a pleasure to perform this study for Occidental de Colombia. Should anyquestions arise or if we may be of further service in any way, please do not hesitate tocontact us.

OCCIDENTAL DE COLOMBIACaño Rondon-1 Well, Form.: Mirador / K2A1___________________________________________________________________________________________RFL 0603116

Table of Contents

Section A - Summary of PVT Methods and Data Page

Summary of analysis methods........................................................................................ A.1-A.3

Summary of PVT data..................................................................................................... A.4

Section B - Summary of Samples Received and Validation Data

Well information............................................................................................................... B.1

Summary of samples received ....................................................................................... B.2

Section C - Compositional Analysis of Wellhead Fluid Sample to C36+

Compositional analysis of wellhead fluid sample to C36+............................................... C.1-C.2

Section D - Constant Composition Expansion

Constant composition expansion at 238 °F..................................................................... D.1-D.2

Graphs from constant composition expansion at 238 °F................................................ D.3

Partial constant composition expansion at 120 °F.......................................................... D.4-D.5

Partial constant composition expansion at 86 °F............................................................ D.6-D.7

Partial constant composition expansion at laboratory ambient temperature (68 °F)....... D.8-D.9

Section E - Differential Vaporization

Differential vaporization data........................................................................................... E.1

Graphs from differential vaporization data....................................................................... E.2

Compositional Analysis of Differential Vaporization Gases to C11+............................... E.3

Compositional Analysis of Differential Vaporization Residue to C36+............................ E.4-E.5

Differential vaporization data converted to surface separator conditions........................ E.6-E.7

Section F - Wellhead Fluid Viscosity Data

Wellhead fluid viscosity data........................................................................................... F.1

Graphs from wellhead fluid viscosity data....................................................................... F.2

Section G - Separator Test Data

Separator test 1............................................................................................................... G.1

Compositional analysis of gas sample from separator test 1.......................................... G.2

Separator test 2............................................................................................................... G.3

Compositional analysis of gas sample from separator test 2.......................................... G.4

Section H - Appendix

Data used in gas compositional calculations................................................................... H.1

Data used in liquid compositional calculations................................................................ H.2

___________________________________________________________________________________________Core LaboratoriesBogotá, Colombia


Section A - Summary of PVT Analysis Methods and Data



Summary of Analysis Methods

Sample ValidationThe bubble point pressure at ambient temperature and free water content of each wellhead samplewere determined as initial quality checks. From this quality control, the measured bubble pointpressures of the samples showed good agreement with one another and very little free water wasmeasured.

Heat TreatmentThe selected wellhead fluid sample was heated to 200°F prior to subsampling for laboratory tests toavoid potential wax deposition problems.

Pressurized Fluid CompositionApproximately 30 cc of pressurized fluid was flashed to atmospheric pressure at 120 °F andseparated into gas and oil phase. The evolved gas and residual liquid were analyzed separately,using gas-liquid chromatography and recombined on a weight basis to produce a C36+ weightpercent composition.

Gas CompositionsGas composition were measured using a "one shot" Varian 3800 gas analyzer using GPA 2286method. The gas chromatograph utilizes 3 columns to clearly identify all of the eluted componentsfrom N2, CO2 and C1 through C11+.

The chromatograph is calibrated weekly using air and synthetic hydrocarbon gas with a knowncomposition. The resultant calibration data is checked statistically against previous calibrationsprior to performing analyses on unknown samples.

Liquid CompositionResidual/stocktank liquid composition were measured using a Varian 3400 chromatograph. Thegas chromatograph utilizes a cold on column, "sandwich injection" technique to ensure that arepresentative sample is injected and swept onto the column. The sample is run twice; first theoriginal fluid and then fluid spiked with n-tetradecane. This allows the laboratory to take intoaccount any heavy end (C36+) losses that may have occurred during the chromatographic run, andmake an accurate correction prior to reporting the liquid composition. The data obtained from thegas chromatograph is in weight %. Calculations to mole% and the plus fractions properties aredescribed later.

The chromatograph for liquid samples is checked daily, using a gravimetric n-paraffin mixcontaining a range of pure components from C8 through C36 and a synthetic gas-oil mix (D2887)with known composition. The resultant calibration data is checked statistically against previouscalibrations prior to performing analyses on unknown samples.

A.1___________________________________________________________________________________________Core LaboratoriesBogotá, Colombia


Summary of Analysis Methods (Continuation)

Calculation of Mole% Compositions and Plus Fraction PropertiesThe residue or stocktank liquid whole sample molecular weight and density are measured using acryscope and a PAAR densitometer respectively.

The mole% data is calculated using GPSA mole weight and density data, where individualcomponents are identified, from carbon dioxide through decanes. Katz and Firoozabadi data areused from undecanes through pentatriacontanes. The residue mole weight and density values arecalculated so that the pseudo average mole weight and density are the same as the measuredvalues. This can lead to anomalous residue mole weights and densities where the Katz andFiroozabadi values may not be suitable for the isomer groups detected.

Other alternatives are to use an assumed C36+ molecular weight and density value, use a linearextrapolation technique for components from C10 to C35 to calculate the C36+ properties or toutilise distillation analysis to produce a C11+, C20+ or C36+ residual oil fraction and physicallymeasure the molecular weight and density.

Constant Composition ExpansionA portion of the wellhead fluid sample was charged to a high pressure visual cell at ambientlaboratory temperature . A partial constant composition expansion was carried out during whichthe bubble point pressure at ambient temperature was determined. This process was repeated fortemperatures of 86°F and 120°F and finally the sample was thermally expanded to the reservoirtemperature for the complete constant composition expansion test. Pressure-volume data for thesingle phase and two phase fluid were also determined. The density of the single phase fluid wasdetermined by weighing measured volumes pumped from the cell at 5000 psig. Density data forother pressures were calculated using the volumetric data.

Differential VaporizationThis was carried out in a high pressure visual cell, at reservoir temperature. At several pressurestages below the observed saturation pressure, the sample was stabilized. The gases evolvedwere then pumped out of the cell and its volume, compressibility and gravities were determined.The final stage was carried out at atmospheric pressure when the residual liquid was pumped out ofthe cell and its volume, density and molecular weight were measured.



Summary of Analysis Methods (Continuation)

Reservoir Fluid ViscosityLive-oil viscosity was measured in an electromagnetic viscometer at reservoir temperature.Viscosity determinations were carried out over a wide range of pressures from above the reservoirpressure to atmospheric pressure.

The measurements were repeated at each pressure stage until five or more results agreed to within0.5%. The densities, obtained from the constant composition expansion and differentialvaporization tests, were used in the calculation of viscosities in centipoise.

Separator TestsFinally, two single-stage separator tests were carried out using a pressurized test separator cell. Aportion of the bottomhole fluid sample, at a pressure above saturation pressure, was pumped intothe separator cell and stabilized at the pressure and temperature required for the first stageseparation. The gas evolved was pumped out of the cell and the volume and composition weredetermined. The final stage was carried out at atmospheric pressure and separator temperatureand the density of the residual liquid was determined.



Summary of PVT Data

Constant Composition Expansion at Laboratory Ambient Temperature (68 °F)

Saturation pressure (bubble-point) 345 psig

Constant Composition Expansion at 86 °F






Average single phase compressibility 8.71 x 10 -6 psi-1(From 4091 psig to 524 psig)

Thermal expansion at 5000 psig 1.0808 vol / vol(Vol at 238°F)/(Vol at 60°F)

Differential Vaporization at 238 °F

Solution gas-oil ratio at saturation pressure 174 scf/bbl of residual oil at 60°F

Relative oil volume at saturation pressure 1.197 vol / vol of residual oil at 60°F

Density at saturation pressure 0.7602 g cm-3

Bottomhole Fluid Viscosity at 238 °F

Viscosity at reservoir pressure 1.211 centipoise at 4091 psig

Viscosity at saturation pressure 0.927 centipoise at 524 psig

Separator Test DataPressure TemperatureFormation Volume Total Solution Stocktank Oil

(psig) (°F) Factor Gas-oil ratio Density at 60 °F(Bl sat/bbl) (scf/bbl) (g cm-3)

Test 1524 238 1.169 143

60 2000 200 0.8580

Test 2524 238 1.180 146

30 2000 200 0.8598



Section B - Summary of Samples Received and Validation Data



Reported Well and Sampling Information

Reservoir and Well Information

Field......................................................................... Caño RondonWell.......................................................................... Caño Rondon-1Reservoir Fluid......................................................... Black Oil Formation................................................................. Mirador / K2A1Current Reservoir Pressure .................................... 4106 psiaReservoir Temperature............................................ 238 °F

Installation................................................................ *DST.......................................................................... *Perforated Interval .................................................. 9,760'-10,378'

Sampling Information

Date sampled........................................................... 11-Jul-06 & 12-Jul-06Time sampled .........................................................Type of samples....................................................... Bottomhole & WellheadSampling company.................................................. Core LaboratoriesSampling Depth...................................................... 3,300 ft

Choke....................................................................... *Status of well............................................................ Shut-In

Bottomhole pressure................................................ *Bottomhole temperature.......................................... *

Wellhead pressure................................................... 415 psiaWellhead temperature............................................. 95.8 °F

Separator pressure ................................................. *Separator temperature ............................................ *

Pressure base.......................................................... 14.7 psiaTemperature base ................................................... 60 °F

Separator gas rate................................................... *Separator oil rate ..................................................... *Water flowrate.......................................................... *Gas gravity (Air = 1)................................................. *Supercompressibility factor...................................... *H2S.......................................................................... *BS&W...................................................................... *API Oil Gravity ......................................................... *

Comments: * Data not provided to Core Laboratories

15:22 & 09:40 - 10:20

B.1___________________________________________________________________________________________Core LaboratoriesBogotá, Colombia


Summary of Samples Received

Bottomhole SamplesLaboratory

Sample Cylinder Sampling :- Bubble point :- Free water SampleNumber Number Pressure Temp. Pressure Temp. drained Volume BSW

(psia) (°F) (psig) (°F) (cc) (cm3) (%)

1.1 -- -- -- -- -- 500 500 100.0

1.2 -- -- -- -- -- 500 500 100.0

Wellhead SamplesLaboratory

Sample Cylinder Sampling :- Bubble point :- Free water SampleNumber Number Pressure Temp. Pressure Temp. drained Volume BSW

(psia) (°F) (psig) (°F) (cc) (cm3) (%)

2.1 59437D 415 120.0 355 72 10 630 0.5

2.2 59386D 415 120.0 349 73 5 660 0.3

Notes:

Bottomhole Samples 1.1 and 1.2 were not transferred to transport cylinders as only water wasrecovered from the sampling operation.

Wellhead Sample 2.2 was selected for compositonal analysis and PVT study.

B.2___________________________________________________________________________________________Core LaboratoriesBogotá, Colombia


Section C - Compositional Analysis of Wellhead Fluid Sample to C36+



Compositional Analysis of Wellhead Sample to C36 plus

Component Mole % Weight %H2 Hydrogen 0.00 0.00H2S Hydrogen Sulphide 0.00 0.00CO2 Carbon Dioxide 0.43 0.11N2 Nitrogen 0.22 0.04C1 Methane 16.55 1.58C2 Ethane 3.30 0.59C3 Propane 1.84 0.49iC4 i-Butane 0.79 0.27nC4 n-Butane 1.52 0.53C5 Neo-Pentane 0.00 0.00iC5 i-Pentane 1.24 0.54nC5 n-Pentane 1.38 0.59C6 Hexanes 2.99 1.54 Methyl-Cyclopentane 1.10 0.56 Benzene 0.08 0.04 Cyclohexane 0.51 0.26C7 Heptanes 4.01 2.40 Methyl-Cyclohexane 2.12 1.25 Toluene 0.31 0.17C8 Octanes 5.27 3.60 EthylBenzene 0.47 0.30 M/P-Xylene 0.47 0.30 O-Xylene 0.20 0.12C9 Nonanes 4.36 3.34 TrimethylBenzene 0.49 0.35C10 Decanes 4.69 3.99C11 Undecanes 4.33 3.81C12 Dodecanes 3.77 3.63C13 Tridecanes 3.96 4.15C14 Tetradecanes 3.43 3.90C15 Pentadecanes 3.38 4.17C16 Hexadecanes 2.70 3.58C17 Heptadecanes 2.41 3.41C18 Octadecanes 2.41 3.62C19 Nonadecanes 2.03 3.20C20 Eicosanes 1.68 2.76C21 Heneicosanes 1.54 2.68C22 Docosanes 1.30 2.38C23 Tricosanes 1.22 2.32C24 Tetracosanes 1.11 2.20C25 Pentacosanes 1.02 2.10C26 Hexacosanes 0.89 1.92C27 Heptacosanes 0.83 1.86C28 Octacosanes 0.78 1.81C29 Nonacosanes 0.73 1.76C30 Triacontanes 0.64 1.60C31 Hentriacontanes 0.59 1.51C32 Dotriacontanes 0.49 1.30C33 Tritriacontanes 0.43 1.17C34 Tetratriacontanes 0.38 1.08C35 Pentatriacontanes 0.37 1.07C36+ Hexatriacontanes + 3.24 14.05_____ _____

Totals : 100.00 100.00Note: 0.00 means less than 0.005. C.1



Compositional Analysis of Wellhead Sample to C36 plus

Calculated Residue Properties

C7 plus Mole % 69.74Mole Weight (g mol-1) 225Density at 60°F (g cm-3) 0.8401



C36 plus Mole % 3.24Molecular Weight (g mol-1) 725Density at 60°F (g cm-3) 0.9389

Calculated Whole Sample Properties

Average mole weight (g mol-1) 167Density at 60°F (g cm-3) 0.7990

C.3___________________________________________________________________________________________Core LaboratoriesBogotá, Colombia


Section D - Constant Composition Expansion (CCE)



Constant Composition Expansion at 238°F

Single-phase Fluid Properties

Saturation pressure (bubble-point pressure) 524 psig

Thermal expansion factor of single phase fluid at 5000 psig(Vol at 238°F)/(Vol at 60°F) 1.0808 vol / vol

Average single phase compressibility(From 4091 psig to 524 psig) 8.71 x 10 -6 psi-1

Density at saturation pressure 0.7602 g cm-3

Mean Single-phase Compressibilities

Pressure Range MeanInitial Pressure Final Pressure Compressibility

(psig) (psig) (psi-1) (1)

5000 4000 6.85 x 10 -6

4000 3000 7.35 x 10 -6

3000 2000 8.07 x 10 -6

2000 524 10.17 x 10 -6

(1) Mean compressibility = (V2-V1) / [(V1+V2)/2] x 1/(P1 - P2)


D.1



Pressure Relative Density Instantaneous Y-Function (3)(psig) Volume (1) (g cm-3) Compressibility

(psi-1 x 10-6) (2)

5000 0.9634 0.7890 6.644091 Reservoir pressure 0.9694 0.7841 7.034000 0.9700 0.7836 7.073000 0.9772 0.7779 7.662000 0.9851 0.7717 8.561000 0.9944 0.7645 10.50900 0.9954 0.7636 10.87800 0.9966 0.7628 11.34700 0.9977 0.7619 11.96600 0.9990 0.7610 12.96524 Saturation pressure 1.0000 0.7602522 1.0020520 1.0040518 1.0060516 1.0080515 1.0091504 1.0208478 1.0515445 1.0978 1.758384 1.2119 1.657302 1.4592 1.526219 1.9311 1.402168 2.4658 1.329127 3.1985 1.27494 4.2094 1.232

(1) Relative Volume = V / Vsat ie. volume at indicated pressure per volume at saturation pressure.(2) Instantaneous compressibility = (V2-V1) / V1 x 1/(P1-P2)(3) Y-function = (Psat - P ) / ((Pabs)(V/Vsat - 1)).


D.2


Graphs of Constant Composition Expansion Data

Relative Volume vs Pressure

Y Function vs Pressure

0.960

0.965

0.970

0.975

0.980

0.985

0.990

0.995

1.000

0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000

Pressure (psig)

Rel

ativ

e V

olum

e, V

/Vsa

t

1.000

1.100

1.200

1.300

1.400

1.500

1.600

1.700

1.800

50 100 150 200 250 300 350 400 450 500

Pressure (psig)

Y-F

un

ctio

n


D.3





Thermal expansion factor of single phase fluid at 5000 lpcm(Vol at 120°F)/(Vol at 60°F) 1.0272 vol / vol

Average single phase compressibility(From 2526 psig to 83 psig) 5.72 x 10 -6 lpc-1




5000 4000 5.02 x 10 -6

4000 3000 5.17 x 10 -6

3000 2000 5.41 x 10 -6

2000 500 6.18 x 10 -6

500 397 7.80 x 10 -6


D.4___________________________________________________________________________________________Core LaboratoriesBogotá, Colombia



Pressure Relative Instantaneous(psig) Volume (1) Compressibility

(psi-1 x 10-6) (2)

5000 0.9746 4.974091 Reservoir pressure 0.9791 5.074000 0.9796 5.093000 0.9846 5.272000 0.9900 5.591000 0.9958 6.31900 0.9965 6.45800 0.9971 6.61700 0.9978 6.81600 0.9985 7.08500 0.9992 7.46400 1.0000 8.33397 Saturation pressure 1.0000394391387384380

Graph of Constant Composition Expansion Data


(1) Relative Volume = V / Vsat ie. volume at indicated pressure per volume at saturation pressure.

0.9750

0.9800

0.9850

0.9900

0.9950

1.0000

0 1000 2000 3000 4000 5000

Pressure, psig

Rel

ativ

e V

olum

e, V

/Vsa

t











5000 4000 4.77 x 10 -6

4000 3000 4.69 x 10 -6

3000 2000 4.74 x 10 -6

2000 500 5.45 x 10 -6

500 364 6.62 x 10 -6






(psi-1 x 10-6) (2)




(1) Relative Volume = V / Vsat ie. volume at indicated pressure per volume at saturation pressure.(2) Instantaneous compressibility = (V2-V1) / V1 x 1/(P1-P2)

0.9800

0.9850

0.9900

0.9950

1.0000

0 1000 2000 3000 4000 5000

Pressure, psig

Rel

ativ

e V

olum

e, V

/Vsa

t











5000 4000 3.94 x 10 -6

4000 3000 4.21 x 10 -6

3000 2000 4.51 x 10 -6

2000 500 5.10 x 10 -6

500 345 5.42 x 10 -6






(psi-1 x 10-6) (2)




(1) Relative Volume = V / Vsat ie. volume at indicated pressure per volume at saturation pressure.(2) Instantaneous compressibility = (V2-V1) / V1 x 1/(P1-P2)

0.9800

0.9850

0.9900

0.9950

1.0000

0 1000 2000 3000 4000 5000

Pressure, psig

Rel

ativ

e V

olum

e, V

/Vsa

t



Section E - Differential Vaporization (DV)



Differential Vaporization at 238°F

Solution Relative Relative Deviation Gas IncrementalPressure Gas-Oil Oil Total Density Factor Formation Gas

(psig) Ratio Volume Volume (g cm-3) (Z) Volume GravityRs(1) Bod(2) Btd(3) Factor (4) (Air = 1.000)

524 174 1.197 1.197 0.7602400 159 1.189 1.314 0.7636 0.964 0.04588 0.749200 120 1.171 2.045 0.7691 0.980 0.09012 0.828100 94 1.156 3.584 0.7742 0.989 0.17017 0.959

0 0 1.091 0.7906 1.605

At 60°F = 1.000

Residual Oil Properties

Density of residual oil 0.8623 g cm-3 at 60°F

API 32.4

(1) GOR in cubic feet of gas at 14.70 psia and 60°F per barrel of residual oil at 60°F.(2) Volume of oil at indicated pressure and temperature per volume of residual oil at 60°F.(3) Volume of oil plus liberated gas at indicated pressure and temperature per volume of residual oil at 60°F.(4) Volume of gas at indicated pressure and temperature per volume at 14.70 psia and 60°F.

Saturation Pressure

E.1___________________________________________________________________________________________Core LaboratoriesBogotá, Colombia


Graphs of Differential Vaporization

Solution Gas-Oil Ratio v Pressure

Relative Oil Volume v Pressure

0

20

40

60

80

100

120

140

160

180

200

0 40 80 120 160 200 240 280 320 360 400 440 480 520

Pressure, psig

Gas

-Oil

Rat

io, s

cf/r

es.b

bl

1.060

1.080

1.100

1.120

1.140

1.160

1.180

1.200

1.220

0 40 80 120 160 200 240 280 320 360 400 440 480 520

Pressure, psig

Rel

ativ

e O

il V

olum

e, V

/Vr



Compositional Analysis of Differential Vaporization Gases to C11+

Sample I.D.

Test Stage 1 2 3 4Stage Pressure (psig) 400 200 100 0

Component (Mole%)

H2 Hydrogen 0.00 0.00 0.00 0.00H2S Hydrogen Sulphide 0.00 0.00 0.00 0.00CO2 Carbon Dioxide 2.43 2.69 2.96 1.11N2 Nitrogen 1.46 0.90 0.62 0.22C1 Methane 80.15 74.22 64.94 35.90C2 Ethane 9.43 11.67 14.16 12.35C3 Propane 1.64 3.02 4.55 9.44iC4 i-Butane 0.72 1.10 1.81 3.69nC4 n-Butane 1.10 1.53 2.85 7.85iC5 i-Pentane 0.61 1.05 1.92 5.70nC5 n-Pentane 0.57 0.89 1.92 5.89C6 Hexanes 0.82 1.41 2.04 7.83C7 Heptanes 0.54 0.85 1.41 5.44C8 Octanes 0.40 0.52 0.68 3.60C9 Nonanes 0.08 0.09 0.11 0.99C10 Decanes 0.04 0.04 0.02 0.01C11+ Undecanes plus 0.01 0.02 0.01 0.00

_____ _____ _____ _____Totals : 100.00 100.00 101.00 100.00

Calculated Gas Properties

Gas Gravity 0.749 0.828 0.959 1.605(Air = 1.000)

Note: 0.00 means less than 0.005.



Compositional Analysis of Differential Vaporization Residue to C36+

Component Mole % Weight %H2 Hydrogen 0.00 0.00H2S Hydrogen Sulphide 0.00 0.00CO2 Carbon Dioxide 0.00 0.00N2 Nitrogen 0.00 0.00C1 Methane 0.00 0.00C2 Ethane 0.07 0.01C3 Propane 0.05 0.01iC4 i-Butane 0.04 0.01nC4 n-Butane 0.15 0.04iC5 i-Pentane 0.53 0.17nC5 n-Pentane 0.69 0.22C6 Hexanes 2.35 0.90C7 Heptanes 6.78 2.85C8 Octanes 9.71 4.70C9 Nonanes 7.51 4.11C10 Decanes 7.16 4.45C11 Undecanes 5.95 3.89C12 Dodecanes 5.21 3.73C13 Tridecanes 5.53 4.30C14 Tetradecanes 4.78 4.04C15 Pentadecanes 4.74 4.34C16 Hexadecanes 3.81 3.76C17 Heptadecanes 3.42 3.60C18 Octadecanes 3.43 3.83C19 Nonadecanes 2.94 3.44C20 Eicosanes 2.36 2.89C21 Heneicosanes 2.13 2.76C22 Docosanes 1.89 2.57C23 Tricosanes 1.75 2.48C24 Tetracosanes 1.58 2.32C25 Pentacosanes 1.45 2.23C26 Hexacosanes 1.28 2.04C27 Heptacosanes 1.23 2.04C28 Octacosanes 1.13 1.95C29 Nonacosanes 1.09 1.94C30 Triacontanes 0.98 1.82C31 Hentriacontanes 0.92 1.75C32 Dotriacontanes 0.77 1.52C33 Tritriacontanes 0.69 1.40C34 Tetratriacontanes 0.64 1.34C35 Pentatriacontanes 0.60 1.29C36+ Hexatriacontanes plus 4.66 15.26

_____ _____Totals : 100.00 100.00

Note: 0.00 means less than 0.005.



Compositional Analysis of Differential Vaporization Residue to C36+

Calculated Residue Properties

C7+ Mole% 96.12Molecular Weight (g mol-1) 231Density at 60°F (g cm-3) 0.8450



C36+ Mole % 4.66Molecular Weight (g mol-1) 737Density at 60°F (g cm-3) 0.9469

Calculated Whole Sample Properties

Average mole weight (g mol-1) 225Density at 60°F (g cm-3) [Measured] 0.8623API 32.4



Differential Vaporization Data Converted to Production Separator Conditions

Oil Solution Formation Gas FormationPressure Density Gas/Oil Volume Volume

(psig) (g cm-3) (scf / bbl) Factor FactorRs(1) Bo(1) Bg(2)

5000 0.7891 1.1264091 Reservoir pressure 0.7839 1.1344000 0.7834 1.1343000 0.7773 1.1432000 0.7707 1.1531000 0.7633 1.164900 0.7625 1.165800 0.7618 1.167700 0.7610 1.168600 0.7604 1.169524 Saturation pressure 0.7602 143 1.169400 0.7636 128 1.161 0.04588200 0.7691 90 1.143 0.09012100 0.7742 65 1.129 0.17017

Notes:

(1) Differential data corrected to surface separator conditions of :-

Stage 1 60 psig and 200°FStage 2 0 psig and 200°F

Rs = Rsfb - (Rsdb - Rsd) x (Bofb / Bodb)

Bo = Bod x (Bofb/Bodb)

(2) Volume of gas at indicated pressure and temperature per volume at 14.7 psia and 60°F.



Differential Vaporization Data Converted to Production Separator Conditions

Oil Solution Formation Gas FormationPressure Density Gas/Oil Volume Volume

(psig) (g cm-3) (scf / bbl) Factor FactorRs(1) Bo(1) Bg(2)

5000 0.7891 1.1374091 Reservoir pressure 0.7839 1.1444000 0.7834 1.1453000 0.7773 1.1542000 0.7707 1.1641000 0.7633 1.175900 0.7625 1.176800 0.7618 1.178700 0.7610 1.179600 0.7604 1.180524 Saturation pressure 0.7602 146 1.180400 0.7636 131 1.172 0.04588200 0.7691 92 1.154 0.09012100 0.7742 67 1.140 0.17017

Notes:

(1) Differential data corrected to surface separator conditions of :-

Stage 1 30 psig and 200°FStage 2 0 psig and 200°F

Rs = Rsfb - (Rsdb - Rsd) x (Bofb / Bodb)

Bo = Bod x (Bofb/Bodb)

(2) Volume of gas at indicated pressure and temperature per volume at 14.7 psia and 60°F.



Section F - Wellhead Fluid Viscosity Data



Wellhead Fluid Viscosity Data at 238°F

Pressure Oil Calculated Oil/Gas(psig) Viscosity Gas Viscosity Viscosity

(cP) (cP) (1) Ratio

5000 1.2804091 Reservoir pressure 1.2114000 1.2043000 1.1242000 1.0431000 0.962600 0.932524 Saturation pressure 0.927400 0.963 0.0139 69.1200 1.046 0.0133 78.4100 1.116 0.0127 88.1

0 1.520

(1) Calculated using the method of Lee, Gonzales and Eakin, JPT, Aug 1966.

F.1___________________________________________________________________________________________Core LaboratoriesBogotá, Colombia


Graphs of Wellhead Fluid Viscosity Data at 238°F

Oil Viscosity Vs Pressure

Single-phase Fluid Viscosity Vs Pressure

0.800

0.900

1.000

1.100

1.200

1.300

1.400

1.500

1.600

0 40 80 120 160 200 240 280 320 360 400 440 480 520 560

Pressurre, psig

Oil

visc

osity

, cP

s

0.800

1.000

1.200

1.400

0 1000 2000 3000 4000 5000

Pressurre, psig

Sin

gle-

phas

e V

isco

sity

, cP

s

F.2___________________________________________________________________________________________Core LaboratoriesBogotá, Colombia


Section G - Separator Test Data



Data from Separator Test 1

Gas-Oil Gas-Oil Oil Formation Separation Gas GravityPressure Temperature Ratio Ratio Density Volume Volume of flashed gas

(psig) (°F) Rsfb (g cm-3) Factor Factor (Air = 1.000)(1) (2) Bofb (3) (4)

524 238 - 143 0.7602 1.169 Saturation Pressure

60 200 110 115 0.8302 1.045 0.968 *0 200 26 28 0.8014 1.071 1.596



API 33.3

Note :

* Evolved gas collected and analysed to C11+.

(1) GOR in cubic feet of gas at 14.70 psia and 60°F per barrel of oil at indicated pressure and temperature.(2) GOR in cubic feet of gas at 14.70 psia and 60°F per barrel of stocktank oil at 60°F.(3) Volume of saturated oil at 524 psig and 238°F per volume of stocktank oil at 60°F.(4) Volume of oil at indicated pressure and temperature per volume of stocktank oil at 60°F.

G.1___________________________________________________________________________________________Core LaboratoriesBogotá, Colombia


Compositional Analysis of Separator Test Gas to C11+

Sampling Date 05-Oct-2006Sample Description Caño Rondon-1 - 60psi Sep Test - First Stage GasCylinder Number 59386DSampling Conditions 60.0 psig @ 200.0°F

Component Mole % Weight %H2 Hydrogen 0.00 0.00H2S Hydrogen Sulphide 0.00 0.00CO2 Carbon Dioxide 2.26 3.57N2 Nitrogen 0.48 0.48C1 Methane 66.50 38.32C2 Ethane 11.95 12.90C3 Propane 5.27 8.34iC4 i-Butane 1.93 4.03nC4 n-Butane 3.40 7.10iC5 i-Pentane 1.93 5.00nC5 n-Pentane 1.88 4.87C6 Hexanes 2.06 6.37C7 Heptanes 1.47 5.29C8 Octanes 0.60 2.46C9 Nonanes 0.15 0.69C10 Decanes 0.11 0.53C11+ Undecanes plus 0.01 0.05

______ ______Totals : 100.00 100.00Note: 0.00 means less than 0.005.Calculated Residue Properties Mole Weight Density

(g mol-1) (g cm-3 @ 60°F )C7+ Heptanes plus 107.4 0.7004C8+ Octanes plus 119.5 0.7195C10+ Decanes plus 135.1 0.7790C11+ Undecanes plus 147.0 0.7890

Calculated Whole Gas PropertiesReal Relative Density 0.9683 (Air=1 @ 14.73 psia & 60°F)Whole Sample Mole Weight 27.85 g mol-1Real Gas Density 1.1866 kg m-3 @ 15°CIdeal Gross Calorific Value 1581.8 BTU.ft-3 @ 14.73psia, 60°FIdeal Net Calorific Value 1443.7 BTU.ft-3 @ 14.73psia, 60°FPseudo Critical Press. 652.5 psiaPseudo Critical Temp. 456.5 RankineGas Compressibility Factor, Z 0.9930 @ 14.73 psia & 60°FGas Viscosity 0.012 cPGPM (C2+) 9.673GPM (C3+) 6.491



Data from Separator Test 2

Gas-Oil Gas-Oil Oil Formation Separation Gas GravityPressure Temperature Ratio Ratio Density Volume Volume of flashed gas

(psig) (°F) Rsfb (g cm-3) Factor Factor (Air = 1.000)(1) (2) Bofb (3) (4)

524 238 - 146 0.7602 1.180 Saturation Pressure

30 200 84 131 0.5574 1.552 1.104 *0 200 14 15 0.8033 1.070 1.584



API 32.9

Note :

* Evolved gas collected and analysed to C11+.

(1) GOR in cubic feet of gas at 14.70 psia and 60°F per barrel of oil at indicated pressure and temperature.(2) GOR in cubic feet of gas at 14.70 psia and 60°F per barrel of stocktank oil at 60°F.(3) Volume of saturated oil at 524 psig and 238°F per volume of stocktank oil at 60°F.(4) Volume of oil at indicated pressure and temperature per volume of stocktank oil at 60°F.



Compositional Analysis of Separator Test Gas to C11+

Sampling Date 05-Oct-2006Sample Description Caño Rondon-1 - 30psi Sep Test - First Stage GasCylinder Number 59386DSampling Conditions 30.0 psig @ 200.0°F

Component Mole % Weight %H2 Hydrogen 0.00 0.00H2S Hydrogen Sulphide 0.00 0.00CO2 Carbon Dioxide 2.16 3.00N2 Nitrogen 0.42 0.37C1 Methane 60.55 30.69C2 Ethane 12.15 11.54C3 Propane 5.92 8.24iC4 i-Butane 2.28 4.19nC4 n-Butane 4.19 7.69iC5 i-Pentane 2.60 5.92nC5 n-Pentane 2.53 5.76C6 Hexanes 3.05 8.30C7 Heptanes 2.31 7.31C8 Octanes 1.18 4.26C9 Nonanes 0.38 1.54C10 Decanes 0.26 1.10C11+ Undecanes plus 0.02 0.09

______ ______Totals : 100.00 100.00Note: 0.00 means less than 0.005.Calculated Residue Properties Mole Weight Density

(g mol-1) (g cm-3 @ 60°F )C7+ Heptanes plus 109.1 0.7035C8+ Octanes plus 120.3 0.7210C10+ Decanes plus 134.9 0.7788C11+ Undecanes plus 147.0 0.7890

Calculated Whole Gas PropertiesReal Relative Density 1.1038 (Air=1 @ 14.73 psia & 60°F)Whole Sample Mole Weight 31.66 g mol-1Real Gas Density 1.3532 kg m-3 @ 15°CIdeal Gross Calorific Value 1790.1 BTU.ft-3 @ 14.73psia, 60°FIdeal Net Calorific Value 1638.0 BTU.ft-3 @ 14.73psia, 60°FPseudo Critical Press. 640.5 psiaPseudo Critical Temp. 487.9 RankineGas Compressibility Factor, Z 0.9905 @ 14.73 psia & 60°FGas Viscosity 0.011 cPGPM (C2+) 12.042GPM (C3+) 8.807



Section H - Appendix



Data Used in Gas Compositional Calculations

Component Mole Weight Density Component Mole Weight Density(g mol-1) (g cm-3 at 60°F) (g mol-1) (g cm-3 at 60°F)

Hydrogen * 2.016 N/A 33DMC5 * 100.20 0.6954Oxygen/(Argon) ** 31.999 1.1410 Cyclohexane * 84.16 0.7827Nitrogen (Corrected) ** 28.013 0.8086 2MC6/23DMC5 * 100.20 0.6917Methane ** 16.043 0.2997 11DMCYC5/3MC6 * 99.20 0.7253Carbon Dioxide ** 44.010 0.8172 t13DMCYC5 * 98.19 0.7528Ethane ** 30.070 0.3558 c13DMCYC5/3EC5 * 99.20 0.7262Hydrogen Sulphide ** 34.080 0.8006 t12DMCYC5 * 98.19 0.7554Propane ** 44.097 0.5065 Heptanes (nC7) * 100.20 0.6875i-Butane ** 58.123 0.5623 22DMC6 * 114.23 0.6994n-Butane ** 58.123 0.5834 MCYC6 * 98.19 0.7740Neo-Pentane * 72.15 0.5968 ECYC5 * 98.19 0.7704i-Pentane ** 72.150 0.6238 223TMC5/24&25DMC6 * 114.23 0.7060n-Pentane ** 72.150 0.6305 ctc124TMCYC5 * 112.21 0.751122DMC4 * 86.18 0.6529 ctc123TMCYC5 * 112.21 0.757423DMC4/CYC5 * 78.16 0.7129 Toluene * 92.14 0.87342MC5 * 86.18 0.6572 Octanes (nC8) * 114.23 0.70633MC5 * 86.18 0.6682 E-Benzene * 106.17 0.8735Hexanes (nC6) * 86.18 0.6631 M/P-Xylene * 106.17 0.867122DMC5 * 100.20 0.6814 O-Xylene * 106.17 0.8840M-C-Pentane * 84.16 0.7533 Nonanes (nC9) * 128.26 0.721224DMC5 * 100.20 0.6757 Decanes *** 134 0.778223TMC4 * 100.20 0.6947 Undecanes *** 147 0.789Benzene * 78.11 0.8820 Dodecanes *** 161 0.800

Data Source Refs :

* ASTM Data Series Publication DS 4B (1991) - Physical Constants of Hydrocarbon and Non-Hydrocarbon Compounds.

** GPA Table of Physical Constants of Paraffin Hydrocarbons and Other Components of Natural Gas, GPA 2145-96.

*** Journal of Petroleum Technology, Nov 1978, Pages 1649-1655. Predicting Phase Behaviour of Condensate/Crude Oil Systems Using Methane Interaction Coefficients - D.L. Katz & A. Firoozabadi.

Note :The gas mole % compositions were calculated from the measured weight % compositions usingthe most detailed analysis results, involving as many of the above components as were identified.The reported component mole % compositions were then sub-grouped into the generic carbonnumber components.

H.1___________________________________________________________________________________________Core LaboratoriesBogotá, Colombia


Data Used in Oil Compositional Calculations

Component Mole Weight Density Component Mole Weight Density(g mol-1) (g cm-3 at 60°F) (g mol-1) (g cm-3 at 60°F)

Hydrogen * 2.016 N/A Undecanes *** 147 0.789Hyd. sulphide ** 34.080 0.8006 Dodecanes *** 161 0.800Carbon Dioxide ** 44.010 0.8172 Tridecanes *** 175 0.811Nitrogen ** 28.013 0.8086 Tetradecanes *** 190 0.822Methane ** 16.043 0.2997 Pentadecanes *** 206 0.832Ethane ** 30.070 0.3558 Hexadecanes *** 222 0.839Propane ** 44.097 0.5065 Heptadecanes *** 237 0.847i-Butane ** 58.123 0.5623 Octadecanes *** 251 0.852n-Butane ** 58.123 0.5834 Nonadecanes *** 263 0.857i-Pentane ** 72.150 0.6238 Eicosanes *** 275 0.862n-Pentane ** 72.150 0.6305 Heneicosanes *** 291 0.867Hexanes ** 86.177 0.6634 Docosanes *** 305 0.872Me-cyclo-pentane * 84.16 0.7533 Tricosanes *** 318 0.877Benzene * 78.11 0.8820 Tetracosanes *** 331 0.881Cyclo-hexane * 84.16 0.7827 Pentacosanes *** 345 0.885Heptanes ** 100.204 0.6874 Hexacosanes *** 359 0.889Me-cyclo-hexane * 98.19 0.7740 Heptacosanes *** 374 0.893Toluene * 92.14 0.8734 Octacosanes *** 388 0.896Octanes ** 114.231 0.7061 Nonacosanes *** 402 0.899Ethyl-benzene * 106.17 0.8735 Triacontanes *** 416 0.902Meta/Para-xylene * 106.17 0.8671 Hentriacontanes *** 430 0.906Ortho-xylene * 106.17 0.8840 Dotriacontanes *** 444 0.909Nonanes ** 128.258 0.7212 Tritriacontanes *** 458 0.9121-2-4-T-M-benzene * 120.19 0.8797 Tetratriacontanes *** 472 0.914Decanes ** 142.285 0.7334 Pentatriacontanes *** 486 0.917

Data Source Refs :

* ASTM Data Series Publication DS 4B (1991) - Physical Constants of Hydrocarbon and Non-Hydrocarbon Compounds.

** GPA Table of Physical Constants of Paraffin Hydrocarbons and Other Components of Natural Gas GPA 2145-96.

*** Journal of Petroleum Technology, Nov 1978, Pages 1649-1655. Predicting Phase Behaviour of Condensate/Crude Oil Systems Using Methane Interaction Coefficients - D.L. Katz & A. Firoozabadi.

Note :The residue mole weight and density values ( eg heptanes plus, undecanes plus, eicosanes plus)are calculated so that the calculated average mole weights and densities correspond with themeasured values. This can lead to anomalous residue mole weights and densities where the Katzand Firoozabadi values may not be suitable for the isomer groups detected.

H.2___________________________________________________________________________________________Core LaboratoriesBogotá, Colombia

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