Caño Rondon-1_PVT Final_Report

Reservoir Fluid Study for OCCIDENTAL DE COLOMBIA Caño Rondon-1 Well, Form.: Mirador / K2A1 RFL 0603116

The analyses, opinions or interpretations in this report are based on observations and material supplied by the client to whom, and for whose whose exclusive and confidential confidential use, this report is made. The interpretations 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 and employees 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 with which such report is used or relied upon.

Core Laboratories Cra 39 Nro. 168-52, Bogotá, Colombia Tel: +57 (1) 6740400 6740400 Fax: +57 (1) 6730060 6730060 Web: http://www.corelab.com http://www.corelab.com

Core Laboratories Cra. 39 Nro. 168-52 Bogotá, Colombia Tel: 57 1 6740400 Web: http://www.corelab.com

October 16th, 2006

Occidental de Colombia. Bogota, Colombia. Attention : Eng. Aldo Caliz Subject: Well: Formation: Interval: File:

Reservoir Fluid Study Caño Rondon-1 Mirador / K2A1 9,760'-10,378' 0603116

Dear Sirs.: Two bottomhole samples and two wellhead samples from the subject well were collected on July 11th and July 12th of 2006 by Core Laboratories representatives and delivered to our fluid fluid laborato laboratory ry in Bogotá Bogotá for use in the performa performance nce of a Reserv Reservoir oir Fluid Fluid Stud Study. y. The samples samples were transported transported to the laboratory laboratory whereupon whereupon sample validation validation and analysis analysis commenced. Preliminary results were reported during the execution of the study and the final report is presented in the following pages. It has been a pleasure to perform this study for Occi Occide dent ntal al de Colo Colomb mbia ia.. Should any questions arise or if we may be of further service in any way, please do not hesitate to

Sincerely, CORE LABORATORIES VENEZUELA, S.A.

David McEvoy Manager Reservoir Fluids Laboratory

OCCIDENTAL DE COLOMBIA Caño Rondon-1_____________________________________ Well, Form.: Mirador / K2A1 RFL 0603116 ___________________________________ ________________ _____________________________________ ______________________________________ ___________________ Table of Contents Section A - Summary of PVT Methods and Data

Page

Summary of analysis methods............... methods......................... ................... .................. ................... ................... .................. ................... ................. .......

A.1-A.3

Summary of PVT data................ data......................... ................... ................... .................. ................... ................... ................... ................... .................. ...........

A.4

Section B - Summary of Samples Received and Validation Data Well information................ information.......................... ................... ................... .................... ................... ................... .................... .................... ................... ................. ........

B.1

Summary Summary of samples samples received received ........ ............ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ....... ...

B.2

Section C - Compositional Analysis of Wellhead Fluid Sample to C36+ Compositional analysis of wellhead fluid sample to C36+................ C36+......................... .................. .................. ............. ....

C.1-C.2

Section D - Constant Composition Expansion Constant composition expansion at 238 °F................... F............................ ................... ................... .................. ................... ............. ...

D.1-D.2

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

D.3

Partial constant composition expansion at 120 °F.................. F............................ ................... .................. ................... ............ ..

D.4-D.5

Partial constant composition expansion at 86 °F................... F............................ .................. ................... ................... ............. ....

D.6-D.7

Partial Partial constant constant composition composition expansion expansion at laboratory laboratory ambient ambient temperatu temperature re (68 °F)...... F)........

D.8-D.9 D.8-D.9

Section E - Differential Vaporization Vaporization Differential vaporization data............... data........................ .................. ................. ................. .................. .................. .................. .................. .............. .....

E.1

Graphs Graphs from differenti differential al vaporizati vaporization on data..... data......... ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ...... ..

E.2

Composition Compositional al Analysis Analysis of Different Differential ial Vaporizati Vaporization on Gases to C11+..... C11+......... ........ ........ ........ ........ ........ ...... ..

E.3

Compositio Compositional nal Analysis Analysis of Different Differential ial Vaporizati Vaporization on Residue Residue to C36+..... C36+......... ........ ........ ........ ........ ....... ...

E.4-E.5 E.4-E.5

Different Differential ial vaporizati vaporization on data converted converted to surface surface separator separator conditions conditions.... ........ ........ ........ ........ ........ ....

E.6-E.7 E.6-E.7

Section F - Wellhead Fluid Viscosity Data Wellhead Wellhead fluid viscosity viscosity data..... data......... ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ...... ..

F.1

Graphs Graphs from wellhead wellhead fluid viscosity viscosity data..... data......... ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ........ ...... ..

F.2

Section G - Separator Test Data Separator test 1................. 1.......................... .................. ................... ................... .................. .................. .................. .................. .................. ................... ............ .. Compositiona Compositionall analysis analysis of gas sample from separator separator test 1... 1....... ........ ........ ........ ........ ........ ........ ........ ........ ....... ... Separator test 2................. 2.......................... .................. ................... ................... .................. .................. .................. .................. .................. ................... ............ .. Compositiona Compositionall analysis analysis of gas sample from separator separator test 2... 2....... ........ ........ ........ ........ ........ ........ ........ ........ ....... ...

G.1 G.2 G.3 G.4

Section H - Appendix Data used in gas compositional calculations............... calculations........................ ................... ................... .................. ................... ............... .....

H.1

Data used in liquid compositional calculations............... calculations........................ .................. ................... ................... .................. ............ ...

H.2

________________________________________________________ _____________________________________ ______________________________________ ___________________________________ ________________ Core Laboratories Bogotá, Colombia

OCCIDENTAL DE COLOMBIA Caño Rondon-1_____________________________________ Well, Form.: Mirador / K2A1 RFL 0603116 ___________________________________ ________________ _____________________________________ ______________________________________ ___________________

Section A - Summary of PVT Analysis Methods and Data

________________________________________________________ _____________________________________ ______________________________________ ___________________________________ ________________ Core Laboratories Bogotá, Colombia

OCCIDENTAL DE COLOMBIA Caño Rondon-1_____________________________________ Well, Form.: Mirador / K2A1 RFL 0603116 ___________________________________ ________________ _____________________________________ ______________________________________ ___________________

Summary of Analysis Methods

Sample Validation The bubble point pressure at ambient temperature and free water content of each wellhead sample were determined determined as initial initial quality checks. From this quality control, control, the measured bubble point point pressures of the samples showed good agreement with one another and very little free water was measured. Heat Treatment The selected wellhead fluid sample was heated to 200°F 200°F prior to subsampling for laboratory tests to avoid potential wax deposition problems. Pressurized Fluid Composition Approximat Approximately ely 30 cc of pressuriz pressurized ed fluid was flashed flashed to atmospheric atmospheric pressure pressure at 120 °F and separated into gas and oil phase. The evolved gas and residual liquid were analyzed analyzed separately, separately, using gas-liquid chromatography and recombined on a weight basis to produce a C36+ weight percent composition. Gas Compositions Gas composition were measured using a "one shot" Varian 3800 gas analyzer using GPA 2286 method. The gas chromatograph utilizes 3 columns to clearly identify all of the eluted components from N2, CO2 and C1 through C11+. The chromatograph chromatograph is calibrated calibrated weekly weekly using air and synthetic synthetic hydrocar hydrocarbon bon gas with a known composition. composition. The resultant calibration calibration data is checked checked statistic statistically ally against previous previous calibratio calibrations ns prior to performing analyses on unknown samples.

Liquid Composition Residual/st Residual/stockta ocktank nk liquid liquid composition composition were measured using a Varian Varian 3400 chromatograp chromatograph. h. The gas chromatograph utilizes a cold on column, "sandwich injection" technique to ensure that a represent representative ative sample sample is injected injected and swept onto the column. The sample is run twice; twice; first the origin original al fluid fluid and then fluid fluid spiked spiked with with n-tetr n-tetrade adecan cane. e. This This allows allows the labora laborator tory y to take into account any heavy end (C36+) losses that may have occurred during the chromatographic run, and make an accurate correction prior to reporting the the liquid composition. The data obtained from the gas chromatogra chromatograph ph is in weight weight %. Calculatio Calculations ns to mole% and the plus fractions fractions properties properties are described later. The chroma chromatog tograp raph h for liquid liquid sample samples s is checke checked d dail daily, y, using using a gravim gravimetr etric ic n-para n-paraffi ffin n mix containing a range of pure components from C8 through C36 and a synthetic gas-oil mix (D2887) with known composition. composition. The resultant resultant calibration calibration data is checked checked statistic statistically ally against previous previous calibrations prior to performing analyses on unknown samples.

________________________________________________________ _____________________________________ ______________________________________ ___________________________________ ________________ A.1 Core Laboratories Bogotá, Colombia

OCCIDENTAL DE COLOMBIA Caño Rondon-1 Well, Form.: Mirador / K2A1 RFL 0603116 ___________________________________________________________________________________________

Summary of Analysis Methods (Continuation)

Calculation of Mole% Compositions and Plus Fraction Properties The residue or stocktank liquid whole sample molecular weight and density are measured using a cryscope and a PAAR densitometer respectively. The mole% data is calculated using GPSA mole weight and density data, where individual components are identified, from carbon dioxide through decanes. Katz and Firoozabadi data are used from undecanes through pentatriacontanes. The residue mole weight and density values are calculated so that the pseudo average mole weight and density are the same as the measured values. This can lead to anomalous residue mole weights and densities where the Katz and Firoozabadi 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 linear extrapolation technique for components from C10 to C35 to calculate the C36+ properties or to utilise distillation analysis to produce a C11+, C20+ or C36+ residual oil fraction and physically measure the molecular weight and density.

Constant Composition Expansion A portion of the wellhead fluid sample was charged to a high pressure visual cell at ambient laboratory temperature . A partial constant composition expansion was carried out during which the bubble point pressure at ambient temperature was determined. This process was repeated for temperatures of 86°F and 120°F and finally the sample was thermally expanded to the reservoir temperature for the complete constant composition expansion test. Pressure-volume data for the single phase and two phase fluid were also determined. The density of the single phase fluid was determined by weighing measured volumes pumped from the cell at 5000 psig. Density data for other pressures were calculated using the volumetric data. Differential Vaporization This was carried out in a high pressure visual cell, at reservoir temperature. At several pressure stages below the observed saturation pressure, the sample was stabilized. The gases evolved were 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 of the cell and its volume, density and molecular weight were measured.

___________________________________________________________________________________________ A.2 Core Laboratories Bogotá, Colombia


Summary of Analysis Methods (Continuation)

Reservoir Fluid Viscosity Live-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 reservoir pressure to atmospheric pressure. The measurements were repeated at each pressure stage until five or more results agreed to within 0.5%. The densities, obtained from the constant composition expansion and differential vaporization tests, were used in the calculation of viscosities i n centipoise.

Separator Tests Finally, two single-stage separator tests were carried out using a pressurized test separator cell. A portion of the bottomhole fluid sample, at a pressure above saturation pressure, was pumped into the separator cell and stabilized at the pressure and temperature required for the first stage separation. The gas evolved was pumped out of the cell and the volume and composition were determined. The final stage was carried out at atmospheric pressure and separator temperature and the density of the residual liquid was determined.



Summary of PVT Data Constant Com osition Ex ansion at Laboratory Ambient Tem erature (68 °F) Saturation pressure (bubble-point)

345 psig

Constant Composition Expansion at 86 °F Saturation pressure (bubble-point)

364 psig


397 psig


524 psig

Average single phase compressibility (From 4091 psig to 524 psig)

8.71

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

x 10 -6 psi-1

1.0808 vol / vol

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 Data Pressure (psig)

TemperatureFormation Volume (°F) Factor (Bl sat/bbl)

Total Solution Gas-oil ratio (scf/bbl)

Stocktank Oil Density at 60 °F (g cm-3)

Test 1 524

238

60 0

200 200

524

238

30 0

200 200

1.169

143 0.8580

Test 2 1.180

146 0.8598



Section B - Summary of Samples Received and Validation Data

___________________________________________________________________________________________ Core Laboratories Bogotá, Colombia


Reported Well and Sampling Information Reservoir and Well Information Field......................................................................... Caño Rondon Well.......................................................................... Caño Rondon-1 Reservoir Fluid......................................................... Black Oil Formation................................................................. Mirador / K2A1 Current Reservoir Pressure .................................... 4106 psia Reservoir Temperature............................................ 238 °F Installation................................................................ * DST.......................................................................... * Perforated Interval .................................................. 9,760'-10,378'

Sam ling Information Date sampled........................................................... 11-Jul-06 & 12-Jul-06 Time sampled ......................................................... 15:22 & 09:40 - 10:20 Type of samples....................................................... Bottomhole & Wellhead Sampling company.................................................. Core Laboratories Sampling Depth...................................................... 3,300 ft Choke....................................................................... * Status of well............................................................ Shut-In Bottomhole pressure................................................ * Bottomhole temperature.......................................... * Wellhead pressure................................................... 415 psia Wellhead temperature............................................. 95.8 °F Separator pressure ................................................. * Separator temperature ............................................ * Pressure base.......................................................... 14.7 psia Temperature 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

___________________________________________________________________________________________ B.1 Core Laboratories Bogotá, Colombia


Summary of Samples Received Bottomhole Samples

Sampling :Pressure Temp. (psia) (°F)

Laboratory Bubble point :Pressure Temp. (psig) (°F)

Sample Number

Cylinder Number

1.1

--

--

--

--

1.2

--

--

--

--

Free water drained (cc)

Sample Volume (cm3)

BSW (%)

--

500

500

100.0

--

500

500

100.0

Free water drained (cc)

Sample Volume (cm3)

BSW (%)

Wellhead Samples

Sampling :Pressure Temp. (psia) (°F)

Laboratory Bubble point :Pressure Temp. (psig) (°F)

Sample Number

Cylinder Number

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 was recovered from the sampling operation. Wellhead Sample 2.2 was selected for compositonal analysis and PVT study.

___________________________________________________________________________________________ B.2 Core Laboratories Bogotá, Colombia


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


OCCIDENTAL DE COLOMBIA Caño Rondon-1 Well, Form.: Mirador / K2A1 RFL 0603116 ___________________________________________________________________________________________ Compositional Analysis of Wellhead Sample to C36 plus Component H2 Hydrogen H2S Hydrogen Sulphide CO2 Carbon Dioxide N2 Nitrogen C1 Methane C2 Ethane C3 Propane iC4 i-Butane nC4 n-Butane C5 Neo-Pentane iC5 i-Pentane nC5 n-Pentane C6 Hexanes Methyl-Cyclopentane Benzene Cyclohexane C7 Heptanes Methyl-Cyclohexane Toluene C8 Octanes EthylBenzene M/P-Xylene O-Xylene C9 Nonanes TrimethylBenzene C10 Decanes C11 Undecanes C12 Dodecanes C13 Tridecanes C14 Tetradecanes C15 Pentadecanes C16 Hexadecanes C17 Heptadecanes C18 Octadecanes C19 Nonadecanes C20 Eicosanes C21 Heneicosanes C22 Docosanes C23 Tricosanes C24 Tetracosanes C25 Pentacosanes C26 Hexacosanes C27 Heptacosanes C28 Octacosanes C29 Nonacosanes C30 Triacontanes C31 Hentriacontanes C32 Dotriacontanes C33 Tritriacontanes C34 Tetratriacontanes C35 Pentatriacontanes C36+ Hexatriacontanes +

Mole % 0.00 0.00 0.43 0.22 16.55 3.30 1.84 0.79 1.52 0.00 1.24 1.38 2.99 1.10 0.08 0.51 4.01 2.12 0.31 5.27 0.47 0.47 0.20 4.36 0.49 4.69 4.33 3.77 3.96 3.43 3.38 2.70 2.41 2.41 2.03 1.68 1.54 1.30 1.22 1.11 1.02 0.89 0.83 0.78 0.73 0.64 0.59 0.49 0.43 0.38 0.37 3.24 _____

Weight % 0.00 0.00 0.11 0.04 1.58 0.59 0.49 0.27 0.53 0.00 0.54 0.59 1.54 0.56 0.04 0.26 2.40 1.25 0.17 3.60 0.30 0.30 0.12 3.34 0.35 3.99 3.81 3.63 4.15 3.90 4.17 3.58 3.41 3.62 3.20 2.76 2.68 2.38 2.32 2.20 2.10 1.92 1.86 1.81 1.76 1.60 1.51 1.30 1.17 1.08 1.07 14.05 _____

___________________________________________________________________________________________ Totals : 100.00 100.00 C.1 Core Laboratories Note: 0.00 means less than 0.005. Bogotá, Colombia

OCCIDENTAL DE COLOMBIA Caño Rondon-1 Well, Form.: Mirador / K2A1 RFL 0603116 ___________________________________________________________________________________________ Compositional Analysis of Wellhead Sample to C36 plus

Calculated Residue Properties C7 plus

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

69.74 225 0.8401

C11 plus


45.66 282 0.8682

C20 plus


17.24 422 0.9035

C36 plus

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

3.24 725 0.9389

Calculated Whole Sample Properties Average mole weight (g mol-1) Density at 60°F (g cm-3)

167 0.7990

___________________________________________________________________________________________ C.3 Core Laboratories Bogotá, 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) Average single phase compressibility (From 4091 psig to 524 psig)

1.0808 vol / vol

8.71 x 10 -6 psi-1

Density at saturation pressure

0.7602 g cm-3

Mean Single-phase Compressibilities Pressure Range Initial Pressure (psig)

Final Pressure (psig)

Mean Compressibility (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 Core Laboratories Bogotá, Colombia


Constant Composition Expansion at 238°F Pressure (psig)

5000 4091 4000 3000 2000 1000 900 800 700 600 524 522 520 518 516 515 504 478 445 384 302 219 168 127 94

Reservoir pressure

Saturation pressure

Relative Volume (1)

Density (g cm-3)

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

0.9634 0.9694 0.9700 0.9772 0.9851 0.9944 0.9954 0.9966 0.9977 0.9990 1.0000 1.0020 1.0040 1.0060 1.0080 1.0091 1.0208 1.0515 1.0978 1.2119 1.4592 1.9311 2.4658 3.1985 4.2094

0.7890 0.7841 0.7836 0.7779 0.7717 0.7645 0.7636 0.7628 0.7619 0.7610 0.7602

6.64 7.03 7.07 7.66 8.56 10.50 10.87 11.34 11.96 12.96

Y-Function (3)

1.758 1.657 1.526 1.402 1.329 1.274 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)).



Graphs of Constant Composition Expansion Data Relative Volume vs Pressure

1.000

0.995

t 0.990 a s V / 0.985 V , e m u 0.980 l o V e 0.975 v i t a l e R 0.970 0.965

0.960 0

500

1000

1500

2000

2500

3000

3500

4000

4500

5000

Pressure (psig)

Y Function vs Pressure

1.800

1.700

1.600

n 1.500 o i t c n 1.400 u F Y 1.300

1.200

1.100

1.000 50

100

150

200

250

300

350

400

450

500

Pressure (psig)




397 psig

Thermal expansion factor of single phase fluid at 5000 lpcm (Vol at 120°F)/(Vol at 60°F) Average single phase compressibility (From 2526 psig to 83 psig)

1.0272 vol / vol

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





5000 4091 4000 3000 2000 1000 900 800 700 600 500 400 397 394

Reservoir pressure

Saturation pressure

Relative Volume (1)


0.9746 0.9791 0.9796 0.9846 0.9900 0.9958 0.9965 0.9971 0.9978 0.9985 0.9992 1.0000 1.0000

4.97 5.07 5.09 5.27 5.59 6.31 6.45 6.61 6.81 7.08 7.46 8.33

391 387 384 380

Graph of Constant Composition Expansion Data Relative Volume vs Pressure

1.0000

0.9950 t a s V / V , 0.9900 e m u l o V e 0.9850 v i t a l e R

0.9800

0.9750 0

1000

2000

3000

4000

5000

Pressure, psig

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




364 psig


1.0091 vol / vol

5.08 x 10 -6 lpc-1




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





5000 4091 4000 3000 2000 1000 900 800 700 600 500 400 364 362

Relative Volume (1)


0.9770 0.9812 0.9817 0.9863 0.9910 0.9961 0.9966 0.9972 0.9978 0.9984 0.9991 0.9998 1.0000

4.84 4.73 4.72 4.69 4.84 5.58 5.74 5.94 6.18 6.48 6.87 7.40

Reservoir pressure

Saturation pressure

360 357 355 352

Graph of Constant Composition Expansion Data Relative Volume vs Pressure 1.0000

t 0.9950 a s V / V , e m u 0.9900 l o V e v i t a l e R

0.9850

0.9800 0

1000

2000

3000

4000

5000

Pressure, psig

(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)




345 psig


1.0000 vol / vol

4.69 x 10 -6 lpc-1




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





5000 4091 4000 3000 2000 1000 900 800 700 600 500 400 345 343 341 339 337 335

Reservoir pressure

Saturation pressure

Relative Volume (1)


0.9791 0.9826 0.9829 0.9871 0.9916 0.9964 0.9970 0.9975 0.9980 0.9986 0.9992 0.9997 1.0000

3.79 4.05 4.08 4.35 4.68 5.21 5.30 5.39 5.50 5.64 5.79 6.00

Graph of Constant Composition Expansion Data Relative Volume vs Pressure 1.0000

t 0.9950 a s V / V , e m u 0.9900 l o V e v i t a l e R

0.9850

0.9800 0

1000

2000

3000

4000

5000

Pressure, psig

(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)



Section E - Differential Vaporization (DV)



Differential Vaporization at 238°F

Pressure (psig)

Solution Gas-Oil Ratio Rs(1)

Relative Oil Volume Bod(2)

Relative Total Volume Btd(3)

524 400 200 100 0

174 159 120 94 0

1.197 1.189 1.171 1.156 1.091

1.197 1.314 2.045 3.584

At 60°F =

Density (g cm-3)

Deviation Factor (Z)

0.7602 0.7636 0.7691 0.7742 0.7906

0.964 0.980 0.989

Gas Formation Volume Factor (4)

Incremental Gas Gravity (Air = 1.000)

Saturation Pressure 0.04588 0.749 0.09012 0.828 0.17017 0.959 1.605

1.000

Residual Oil Properties Density of residual oil

0.8623

API

32.4

g cm-3 at 60°F

(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.

___________________________________________________________________________________________ E.1 Core Laboratories Bogotá, Colombia


Graphs of Differential Vaporization Solution Gas-Oil Ratio v Pressure 200 180 160 l b b . 140 s e r / f 120 c s , o i t 100 a R l i 80 O s a 60 G

40 20 0 0

40

80

120

160

200

240

280

320

360

400

440

480

520

400

440

480

520

Pressure, psig

Relative Oil Volume v Pressure 1.220 1.200 r 1.180 V / V , e 1.160 m u l o V 1.140 l i O e v 1.120 i t a l e R1.100

1.080 1.060 0

40

80

120

160

200

240

280

320

360

Pressure, psig



Compositional Analysis of Differential Vaporization Gases to C11+ Sample I.D. Test Stage Stage Pressure (psig)

1 400

2 200

3 100

4 0

Component (Mole%) H2 H2S CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6 C7 C8 C9 C10 C11+

Hydrogen Hydrogen Sulphide Carbon Dioxide Nitrogen Methane Ethane Propane i-Butane n-Butane i-Pentane n-Pentane Hexanes Heptanes Octanes Nonanes Decanes Undecanes plus Totals :

0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.43 2.69 2.96 1.11 1.46 0.90 0.62 0.22 80.15 74.22 64.94 35.90 9.43 11.67 14.16 12.35 1.64 3.02 4.55 9.44 0.72 1.10 1.81 3.69 1.10 1.53 2.85 7.85 0.61 1.05 1.92 5.70 0.57 0.89 1.92 5.89 0.82 1.41 2.04 7.83 0.54 0.85 1.41 5.44 0.40 0.52 0.68 3.60 0.08 0.09 0.11 0.99 0.04 0.04 0.02 0.01 0.01 0.02 0.01 0.00 _____ _____ _____ _____ 100.00 100.00 101.00 100.00

Calculated Gas Properties Gas Gravity (Air = 1.000)

0.749

0.828

0.959

1.605

Note: 0.00 means less than 0.005.



Compositional Analysis of Differential Vaporization Residue to C36+

H2 H2S CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6 C7 C8 C9 C10 C11 C12 C13 C14 C15 C16 C17 C18 C19 C20 C21 C22 C23 C24 C25 C26 C27 C28 C29 C30 C31 C32 C33 C34 C35 C36+

Component Hydrogen Hydrogen Sulphide Carbon Dioxide Nitrogen Methane Ethane Propane i-Butane n-Butane i-Pentane n-Pentane Hexanes Heptanes Octanes Nonanes Decanes Undecanes Dodecanes Tridecanes Tetradecanes Pentadecanes Hexadecanes Heptadecanes Octadecanes Nonadecanes Eicosanes Heneicosanes Docosanes Tricosanes Tetracosanes Pentacosanes Hexacosanes Heptacosanes Octacosanes Nonacosanes Triacontanes Hentriacontanes Dotriacontanes Tritriacontanes Tetratriacontanes Pentatriacontanes Hexatriacontanes plus Totals :

Mole % 0.00 0.00 0.00 0.00 0.00 0.07 0.05 0.04 0.15 0.53 0.69 2.35 6.78 9.71 7.51 7.16 5.95 5.21 5.53 4.78 4.74 3.81 3.42 3.43 2.94 2.36 2.13 1.89 1.75 1.58 1.45 1.28 1.23 1.13 1.09 0.98 0.92 0.77 0.69 0.64 0.60 4.66 _____ 100.00

Weight % 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.01 0.04 0.17 0.22 0.90 2.85 4.70 4.11 4.45 3.89 3.73 4.30 4.04 4.34 3.76 3.60 3.83 3.44 2.89 2.76 2.57 2.48 2.32 2.23 2.04 2.04 1.95 1.94 1.82 1.75 1.52 1.40 1.34 1.29 15.26 _____ 100.00




Compositional Analysis of Differential Vaporization Residue to C36+ Calculated Residue Properties C7+

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

96.12 231 0.8450

C11+


64.96 286 0.8707

C20+


25.15 426 0.9063

C36+

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

4.66 737 0.9469

Calculated Whole Sample Properties Average mole weight (g mol-1) Density at 60°F (g cm-3) [Measured] API

225 0.8623 32.4



Differential Vaporization Data Converted to Production Separator Conditions Oil Density (g cm-3)

Pressure (psig)

5000 4091 4000 3000 2000 1000 900 800 700 600 524 400 200 100

Reservoir pressure

Saturation pressure

0.7891 0.7839 0.7834 0.7773 0.7707 0.7633 0.7625 0.7618 0.7610 0.7604 0.7602 0.7636 0.7691 0.7742

Solution Gas/Oil (scf / bbl) Rs(1)

Formation Volume Factor Bo(1)

Gas Formation Volume Factor Bg(2)

143 128 90 65

1.126 1.134 1.134 1.143 1.153 1.164 1.165 1.167 1.168 1.169 1.169 1.161 1.143 1.129

0.04588 0.09012 0.17017

Notes: (1) Differential data corrected to surface separator conditions of :Sta ge 1 Stage 2

60 psig and 200°F 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 Density (g cm-3)

Pressure (psig)

5000 4091 4000 3000 2000 1000 900 800 700 600 524 400 200 100

Reservoir pressure

Saturation pressure

0.7891 0.7839 0.7834 0.7773 0.7707 0.7633 0.7625 0.7618 0.7610 0.7604 0.7602 0.7636 0.7691 0.7742

Solution Gas/Oil (scf / bbl) Rs(1)

Formation Volume Factor Bo(1)

Gas Formation Volume Factor Bg(2)

146 131 92 67

1.137 1.144 1.145 1.154 1.164 1.175 1.176 1.178 1.179 1.180 1.180 1.172 1.154 1.140

0.04588 0.09012 0.17017

Notes: (1) Differential data corrected to surface separator conditions of :Sta ge 1 Stage 2

30 psig and 200°F 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 (psig) 5000 4091 4000 3000 2000 1000 600 524 400 200 100 0

Oil Viscosity (cP) Reservoir pressure

Saturation pressure

Calculated Gas Viscosity (cP) (1)

Oil/Gas Viscosity Ratio

0.0139 0.0133 0.0127

69.1 78.4 88.1

1.280 1.211 1.204 1.124 1.043 0.962 0.932 0.927 0.963 1.046 1.116 1.520

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

___________________________________________________________________________________________ F.1 Core Laboratories Bogotá, Colombia


Graphs of Wellhead Fluid Viscosity Data at 238°F Oil Viscosity Vs Pressure

1.600 1.500 1.400 s P 1.300 c , y t i s 1.200 o c s i v l 1.100 i O

1.000 0.900 0.800 0

40

80

120

160

200

240

280

320

360

400

440

480

520

560

Pressurre, psig

Single-phase Fluid Viscosity Vs Pressure 1.400

s P c , y 1.200 t i s o c s i V e s a h p e 1.000 l g n i S

0.800 0

1000

2000

3000

4000

5000

Pressurre, psig

___________________________________________________________________________________________ F.2 Core Laboratories Bogotá, Colombia


Section G - Separator Test Data



Data from Separator Test 1

Pressure (psig)

Temperature (°F)

Gas-Oil Ratio

Oil Density (g cm-3)

(1)

Gas-Oil Ratio Rsfb (2)

Formation Volume Factor Bofb (3)

1.169

524

238

-

143

0.7602

60 0

200 200

110 26

115 28

0.8302 0.8014

Separation Gas Gravity Volume of flashed gas Factor (Air = 1.000) (4)

Saturation Pressure 1.045 1.071

0.968 * 1.596


0.8580

API

33.3

g cm-3 at 60°F

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 Laboratories Bogotá, Colombia


Compositional Analysis of Separator Test Gas to C11+ Sampling Date Sample Description Cylinder Number Sampling Conditions

H2 H2S CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6 C7 C8 C9 C10 C11+

Component Hydrogen Hydrogen Sulphide Carbon Dioxide Nitrogen Methane Ethane Propane i-Butane n-Butane i-Pentane n-Pentane Hexanes Heptanes Octanes Nonanes Decanes Undecanes plus Totals :

05-Oct-2006 Caño Rondon-1 - 60psi Sep Test - First Stage Gas 59386D 60.0 psig @ 200.0°F Mole % 0.00 0.00 2.26 0.48 66.50 11.95 5.27 1.93 3.40 1.93 1.88 2.06 1.47 0.60 0.15 0.11 0.01 ______ 100.00

Weight % 0.00 0.00 3.57 0.48 38.32 12.90 8.34 4.03 7.10 5.00 4.87 6.37 5.29 2.46 0.69 0.53 0.05 ______ 100.00

Mole Weight (g mol-1) 107.4 119.5 135.1 147.0

Density (g cm-3 @ 60°F ) 0.7004 0.7195 0.7790 0.7890


Calculated Residue Properties C7+ C8+ C10+ C11+

Heptanes plus Octanes plus Decanes plus Undecanes plus Calculated Whole Gas Properties Real Relative Density Whole Sample Mole Weight Real Gas Density Ideal Gross Calorific Value Ideal Net Calorific Value Pseudo Critical Press. Pseudo Critical Temp. Gas Compressibility Factor, Z Gas Viscosity GPM (C2+) GPM (C3+)

0.9683 27.85 1.1866 1581.8 1443.7 652.5 456.5 0.9930 0.012 9.673 6.491

(Air=1 @ 14.73 psia & 60°F) g mol-1 kg m-3 @ 15°C BTU.ft-3 @ 14.73psia, 60°F BTU.ft-3 @ 14.73psia, 60°F psia Rankine @ 14.73 psia & 60°F cP



Data from Separator Test 2

Pressure (psig)

Temperature (°F)

Gas-Oil Ratio

Oil Density (g cm-3)

(1)

Gas-Oil Ratio Rsfb (2)

Formation Volume Factor Bofb (3)

1.180

524

238

-

146

0.7602

30 0

200 200

84 14

131 15

0.5574 0.8033

Separation Gas Gravity Volume of flashed gas Factor (Air = 1.000) (4)

Saturation Pressure 1.552 1.070

1.104 * 1.584


0.8598

API

32.9

g cm-3 at 60°F

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 Sample Description Cylinder Number Sampling Conditions

H2 H2S CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6 C7 C8 C9 C10 C11+

Component Hydrogen Hydrogen Sulphide Carbon Dioxide Nitrogen Methane Ethane Propane i-Butane n-Butane i-Pentane n-Pentane Hexanes Heptanes Octanes Nonanes Decanes Undecanes plus Totals :

05-Oct-2006 Caño Rondon-1 - 30psi Sep Test - First Stage Gas 59386D 30.0 psig @ 200.0°F Mole % 0.00 0.00 2.16 0.42 60.55 12.15 5.92 2.28 4.19 2.60 2.53 3.05 2.31 1.18 0.38 0.26 0.02 ______ 100.00

Weight % 0.00 0.00 3.00 0.37 30.69 11.54 8.24 4.19 7.69 5.92 5.76 8.30 7.31 4.26 1.54 1.10 0.09 ______ 100.00

Mole Weight (g mol-1) 109.1 120.3 134.9 147.0

Density (g cm-3 @ 60°F ) 0.7035 0.7210 0.7788 0.7890


Calculated Residue Properties C7+ C8+ C10+ C11+

Heptanes plus Octanes plus Decanes plus Undecanes plus Calculated Whole Gas Properties Real Relative Density Whole Sample Mole Weight Real Gas Density Ideal Gross Calorific Value Ideal Net Calorific Value Pseudo Critical Press. Pseudo Critical Temp. Gas Compressibility Factor, Z Gas Viscosity GPM (C2+) GPM (C3+)

1.1038 31.66 1.3532 1790.1 1638.0 640.5 487.9 0.9905 0.011 12.042 8.807

(Air=1 @ 14.73 psia & 60°F) g mol-1 kg m-3 @ 15°C BTU.ft-3 @ 14.73psia, 60°F BTU.ft-3 @ 14.73psia, 60°F psia Rankine @ 14.73 psia & 60°F cP



Section H - Appendix



Data Used in Gas Compositional Calculations Component

Hydrogen Oxygen/(Argon) Nitrogen (Corrected) Methane Carbon Dioxide Ethane Hydrogen Sulphide Propane i-Butane n-Butane Neo-Pentane i-Pentane n-Pentane 22DMC4 23DMC4/CYC5 2MC5 3MC5 Hexanes (nC6) 22DMC5 M-C-Pentane 24DMC5 223TMC4 Benzene

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

2.016 31.999 28.013 16.043 44.010 30.070 34.080 44.097 58.123 58.123 72.15 72.150 72.150 86.18 78.16 86.18 86.18 86.18 100.20 84.16 100.20 100.20 78.11

N/A 1.1410 0.8086 0.2997 0.8172 0.3558 0.8006 0.5065 0.5623 0.5834 0.5968 0.6238 0.6305 0.6529 0.7129 0.6572 0.6682 0.6631 0.6814 0.7533 0.6757 0.6947 0.8820

33DMC5 Cyclohexane 2MC6/23DMC5 11DMCYC5/3MC6 t13DMCYC5 c13DMCYC5/3EC5 t12DMCYC5 Heptanes (nC7) 22DMC6 MCYC6 ECYC5 223TMC5/24&25DMC6 ctc124TMCYC5 ctc123TMCYC5 Toluene Octanes (nC8) E-Benzene M/P-Xylene O-Xylene Nonanes (nC9) Decanes Undecanes Dodecanes

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

100.20 84.16 100.20 99.20 98.19 99.20 98.19 100.20 114.23 98.19 98.19 114.23 112.21 112.21 92.14 114.23 106.17 106.17 106.17 128.26 134 147 161

0.6954 0.7827 0.6917 0.7253 0.7528 0.7262 0.7554 0.6875 0.6994 0.7740 0.7704 0.7060 0.7511 0.7574 0.8734 0.7063 0.8735 0.8671 0.8840 0.7212 0.778 0.789 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 using the 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 carbon number components.

___________________________________________________________________________________________ H.1 Core Laboratories Bogotá, Colombia


Data Used in Oil Compositional Calculations Component

Hydrogen Hyd. sulphide Carbon Dioxide Nitrogen Methane Ethane Propane i-Butane n-Butane i-Pentane n-Pentane Hexanes Me-cyclo-pentane Benzene Cyclo-hexane Heptanes Me-cyclo-hexane Toluene Octanes Ethyl-benzene Meta/Para-xylene Ortho-xylene Nonanes 1-2-4-T-M-benzene Decanes

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

2.016 34.080 44.010 28.013 16.043 30.070 44.097 58.123 58.123 72.150 72.150 86.177 84.16 78.11 84.16 100.204 98.19 92.14 114.231 106.17 106.17 106.17 128.258 120.19 142.285

N/A 0.8006 0.8172 0.8086 0.2997 0.3558 0.5065 0.5623 0.5834 0.6238 0.6305 0.6634 0.7533 0.8820 0.7827 0.6874 0.7740 0.8734 0.7061 0.8735 0.8671 0.8840 0.7212 0.8797 0.7334

Undecanes Dodecanes Tridecanes Tetradecanes Pentadecanes Hexadecanes Heptadecanes Octadecanes Nonadecanes Eicosanes Heneicosanes Docosanes Tricosanes Tetracosanes Pentacosanes Hexacosanes Heptacosanes Octacosanes Nonacosanes Triacontanes Hentriacontanes Dotriacontanes Tritriacontanes Tetratriacontanes Pentatriacontanes

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

147 161 175 190 206 222 237 251 263 275 291 305 318 331 345 359 374 388 402 416 430 444 458 472 486

0.789 0.800 0.811 0.822 0.832 0.839 0.847 0.852 0.857 0.862 0.867 0.872 0.877 0.881 0.885 0.889 0.893 0.896 0.899 0.902 0.906 0.909 0.912 0.914 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 the measured values. This can lead to anomalous residue mole weights and densities where the Katz and Firoozabadi values may not be suitable for the isomer groups detected.

___________________________________________________________________________________________ H.2 Core Laboratories Bogotá, Colombia

Caño Rondon-1_PVT Final_Report

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