Piñuna+5

RFL 2010-36721
Final Report
of
Reservoir Fluid Study
for
VETRA Exploración y Producción Colombia S.A.
PENCOR Advanced Fluid Studies
A Product of
Piñuña Field
Piñuña-5 Well
8-Oct-2010
6316 Windfern Rd. Houston, Texas 77040, USA
Tel: 713-328-2673 Fax: 713-328-2697 Web: http://www.corelab.com
The analyses, opinions or interpretations in this report are based upon observations and material supplied by the client to whom, and for
whose exclusive and confidential use, this report has been made. The interpretations or opinions expressed represent the best judgement
of Core Laboratories. Core Laboratories and its officers and employees assume no responsibility and make no warranty or representations,
express or implied, as to the productivity, proper operation or profitability of any oil, gas, coal or any other mineral, property, well or sand
formation in connection with which such report is used or relied upon for any reason whatsoever.

Core Laboratories, LP
Pencor Advanced Fluid Studies
6316 Windfern Rd,
Houston, TX. USA 77040
Fax: 713-328-2697
Tel: 713-328-2674
Web: http://www.corelab.com
Sincerely,
David McEvoy
Project Manager
PENCOR Advanced Fluid Studies Laboratory
October 8th, 2010
Carrera 7 No. 71-52
Torre A Piso 10
Bogotá, Colombia
Attention : Eng. Javier Aguillon
Subject: Reservoir Fluid Study
Field: Piñuña
Well: Piñuña-5
File: 2010-36721
Dear Eng. Aguillon;
A series of bottom-hole reservoir fluid samples were collected from the subject well on
June 26, 2010 by Core Laboratories representatives. The samples were received by our
Pencor Advanced Fluid Studies Laboratory in Houston, USA on September 14, 2010.
Initial sample validation and quality control procedures commenced upon receipt, and the
laboratory received approval to perform the Reservoir Fluid / PVT study on the selected
sample on September 23, 2010.
The final report containing the data for the completed laboratory study is presented in the
following pages.
It has been a pleasure to be of service to VETRA Exploración y Producción Colombia S.A.
Should any questions arise or if we may be of further service in any way, please do not
hesitate to contact us.

Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Table of Contents
Section A - Summary of Analysis Methods and PVT Data Page
Summary of analysis methods......................................................................................... A.1-A.2
Summary of PVT Data.................................................................................................... A.3
Section B - Summary of Samples Received and Validation Data
Well and sampling information........................................................................................ B.1
Summary of samples received........................................................................................ B.2
Section C - Compositional Analysis of Bottom-hole Reservoir Fluid Sample
Compositional analysis of bottom-hole sample to C36+................................................... C.1-C.2
Section D- Constant Composition Expansion (CCE)
Constant composition expansion data at 203 °F............................................................... D.1-D.2
Graphs of constant composition expansion data at 203 °F............................................... D.3
Section E - Differential Vaporization (DV)
Differential vaporization data............................................................................................ E.1
Graphs from differential vaporization................................................................................ E.2
Produced gas and residual liquid compostions from differential vaporization.................... E.3-E.5
Differential vaporization data converted to production separator conditions...................... E.6
Section F - Separator Test Data
Data from separator test.................................................................................................. F.1
Compositional analysis of produced gases and stocktank oil from separator test............. F.2-F.4
Section G - Reservoir Fluid Viscosity Data
Reservoir fluid viscosity at 203 °F.................................................................................... G.1
Section H - Appendix
Data used in gas compositional calculations.................................................................... H.1
Data used in liquid compositional calculations.................................................................. H.2
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Core Laboratories LP

Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Section A - Summary of Analysis Methods and PVT Data
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Summary of Analyses Methods
Sample Validation
The visual bubble point pressure at reservoir temperature, and free water content, were
measured as initial quality checks for each bottomhole sample. The visual bubble point is
obtained by charging a small volume of sample to a PVT cell, and quickly lowering the pressure
until the first gas bubble is observed. The results for the two samples showed good agreement.
The sample is checked for the presence of free water, which is drained and the volume
measured. The entrained water content was determined by Karl Fischer titration.
Based on the sample evaluations, cylinder no. 818386 was selected for full PVT analysis.
Heat Treatment
The selected sample cylinder was heated to the reservoir temperature of 203 °F prior to
subsampling to avoid potential wax deposition problems and ensure representative sample
transfers at all stages of testing.
Pressurized Fluid Composition
Approximately 25 cc of pressurized fluid was flashed to atmospheric pressure at 120 °F and
separated into its respective gas and oil phases. The evolved gas and residual liquid were
analyzed separately, using gas-liquid chromatography and recombined on a weight basis to
produce a C36+ weight percent composition.
Gas Compositions
Gas compositions were measured using a "one shot" Varian 3800 gas analyzer using method
GPA 2286. The gas chromatograph utilizes 3 columns to clearly identify all the eluted
components from N2, CO2 and C1 through C11+.
The chromatograph is calibrated weekly using air and synthetic hydrocarbon gas with a known
composition. The resultant calibration data is checked statistically against previous calibrations
prior to performing analyses on unknown samples.
Liquid Composition
Residual / stocktank liquid composition were measured using a Varian 3600 chromatograph.
The gas chromatograph utilizes a cold on column, "sandwich injection" technique to ensure that
a representative sample is injected and swept onto the column. The sample is run twice; first
the original fluid and then the fluid spiked with n-tetradecane. This allows the laboratory 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 liquid composition. The data
obtained from the gas chromatograph is in weight %. Calculations to mole% and the plus
fractions properties are described later.
The chromatograph is checked daily, using a gravimetric n-paraffin mix containing a range of
pure components from C8 through C36 and a synthetic gas-oil mix (D2887) with a known
composition. The resultant calibration data is checked statistically against previous calibrations
prior to perform analyses on unknown samples.
A.1
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Summary of Analyses 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 densimeter 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.
Constant Composition Expansion
A portion of the reservoir fluid sample was charged to a high pressure visual cell at reservoir
temperature. A constant composition expansion was carried out during which the bubble point
pressure at reservoir temperature, and pressure-volume data for the single phase and two
phase fluid, were determined. The density of the single phase fluid was measured via an Anton
Paar® high-pressure densitometer connected directly to the cell at 5000 psig. Density data for
other pressures were calculated using the data from the pressure-volume relationship.
Differential Vaporization
The differential vaporization test was carried out in a high pressure visual cell at reservoir
temperature. Beginning with the fluid sample in a single-phase state above the measured
saturation pressure, the pressure was lowered to the first depletion stage pressure and
thoroughly equilibrated. The evolved gas was displaced from the cell and its volume,
compressibility, gravity and molar composition were measured. This process was repeated at
successively lower pressure stages until the last stage was reached. The final stage was
carried out at atmospheric pressure when the residual liquid was pumped out of the cell and its
volume, density, molecular weight and composition were measured.
Separator Test
A single-stage separator test was carried out using a pressurized test separator cell. A portion
of the recombined reservoir fluid sample was charged to the cell and stabilized at the pressure
and temperature required for the first stage of separation. The gas evolved was pumped out of
the cell and the volume and composition were measured. The final (stocktank) stage was
carried out at atmospheric pressure and 60°F and the density and composition of the residual
liquid were determined.
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 atmosheric 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 in centipoise.
A.2
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Summary of Laboratory Data
Constant Composition Expansion of Reservoir Fluid at 203 °F
Saturation pressure (bubble-point) 942 psig
Average single phase compressibility 8.07 x 10 -6 psi-1
(From 3485 psig to 942 psig)
Density at saturation pressure 0.7996 g cm-3
Differential Vaporization at 203 °F
Solution gas-oil ratio at saturation pressure 262 scf/bbl of residual oil at 60°F
Relative oil volume at saturation pressure 1.216 vol / vol of residual oil at 60°F
Density of residual oil 0.8983 g cm-3 at 60°F
Separator Test Data
Pressure Temperature Formation Volume Total Solution Stocktank Oil
(psig) (°F) Factor Gas-oil ratio Density at 60 °F
(Bl sat/bbl) (scf/bbl) (g cm-3)
942 203 1.163 191
45 100 168
0 60 23 0.8899
Reservoir Fluid Viscosity at 203 °F
Viscosity at reservoir pressure 2.129 centipoise at 3485 psig
Viscosity at saturation pressure 1.637 centipoise at 942 psig
Viscosity at atmospheric pressure 4.544 centipoise at 0 psig
A.3
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Section B - Summary Of Samples Received And Validation Data
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Reported Well and Sampling Information
Reservoir and well information
Field...................................................................... Piñuña
Well....................................................................... Piñuña-5
Reservoir Fluid...................................................... Black Oil
Formation.............................................................. Villeta (U Sand)
Current Reservoir Pressure .................................. 3500 psia
Reservoir Temperature.......................................... 203 °F
Installation............................................................. *
DST....................................................................... *
Perforated Interval ................................................ 9,508 - 9,524 ft.; 9,544 - 9,558 ft.;
9,574 - 9,580 ft.
Sampling information
Date sampled........................................................ 26-Jun-10
Time sampled ....................................................... 12:00
Type of samples.................................................... BHS
Sampling company................................................ Core Laboratories
Sampling Depth.................................................... 7,650 ft.
Choke.................................................................... *
Status of well......................................................... Pumping (ESP)
Bottomhole pressure.............................................. 3283 psia at sampling depth
Bottomhole temperature........................................ 230 °F at sampling depth (estimated)
Wellhead pressure................................................. *
Wellhead temperature........................................... *
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
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Summary of Samples Received
Bottomhole samples
Entrained
Sample Cylinder Water Sample Water
number number pressure Temp. Pressure Temp. recovered volume Content
(psia) (°F) (psig) (°F) (cc) (cc) (%)
1.1 818408 3283 230 * 820 203 0 600 4.15
1.2 818386 3283 230 * 840 203 7 600 3.03
Notes:
* The temperature at sampling depth is estimated.
Sample cylinder number 818386 was selected for PVT analysis.
The samples were subjected to a dehydration procedure consisting of 48 hours of thermal cycling.
Following this period subsamples were removed and measured for entrained water content.
Cylinder 818408 was reduced to a 0.76 wt. % water content and cylinder 818386 was reduced to
0.05 wt. %.
Laboratory visual
Sampling bubble point
B.2
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Section C - Compositional Analysis of Bottom-hole Reservoir Fluid Sample
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Compositional Analysis of Bottomhole Sample to C36 plus
Component Mole % Weight %
H2 Hydrogen 0.00 0.00
H2S Hydrogen Sulphide 0.00 0.00
CO2 Carbon Dioxide 1.59 0.37
N2 Nitrogen 1.02 0.15
C1 Methane 13.86 1.19
C2 Ethane 4.33 0.70
C3 Propane 7.95 1.88
iC4 i-Butane 1.72 0.53
nC4 n-Butane 4.20 1.31
C5 Neo-Pentane 0.02 0.01
iC5 i-Pentane 2.00 0.77
nC5 n-Pentane 1.93 0.74
C6 Hexanes 2.55 1.17
Methyl-Cyclopentane 1.06 0.48
Benzene 0.17 0.07
Cyclohexane 0.42 0.19
C7 Heptanes 2.85 1.53
Methyl-Cyclohexane 1.07 0.56
Toluene 0.47 0.23
C8 Octanes 3.31 2.02
EthylBenzene 0.47 0.26
M/P-Xylene 0.48 0.27
O-Xylene 0.28 0.16
C9 Nonanes 2.87 1.97
TrimethylBenzene 0.32 0.20
C10 Decanes 3.21 2.45
C11 Undecanes 2.95 2.32
C12 Dodecanes 2.59 2.23
C13 Tridecanes 2.96 2.77
C14 Tetradecanes 2.38 2.41
C15 Pentadecanes 2.35 2.59
C16 Hexadecanes 1.95 2.32
C17 Heptadecanes 1.79 2.27
C18 Octadecanes 1.90 2.55
C19 Nonadecanes 1.80 2.54
C20 Eicosanes 1.34 1.97
C21 Heneicosanes 1.23 1.91
C22 Docosanes 1.14 1.87
C23 Tricosanes 1.06 1.81
C24 Tetracosanes 0.98 1.73
C25 Pentacosanes 0.93 1.71
C26 Hexacosanes 0.82 1.57
C27 Heptacosanes 0.82 1.65
C28 Octacosanes 0.76 1.57
C29 Nonacosanes 0.76 1.63
C30 Triacontanes 0.72 1.61
C31 Hentriacontanes 0.68 1.57
C32 Dotriacontanes 0.58 1.39
C33 Tritriacontanes 0.54 1.32
C34 Tetratriacontanes 0.51 1.30
C35 Pentatriacontanes 0.48 1.24
C36+ Hexatriacontanes + 7.83 32.94
_____ _____
Totals : 100.000 100.000
C.1
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Compositional Analysis of Bottomhole Sample to C36 plus
Calculated Residue Properties
C7 plus Mole % 58.83
Mole Weight (g mol-1) 290
Density at 60°F (g cm-3) 0.9047
Molecular Weight (g mol-1) 786
Calculated Whole Sample Properties
Average mole weight (g mol-1) 187
C.2
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Section D- Constant Composition Expansion (CCE)
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Constant Composition Expansion at 203°F
Single-phase Fluid Properties
Saturation pressure (bubble-point pressure) 942 psig
Average single phase compressibility
(From 3485 psig to 942 psig) 8.07 x 10 -6 psi-1
Density at saturation pressure 0.7996 g cm-3
Mean Single-phase Compressibilities
Pressure Range Mean
Initial Pressure Final Pressure Compressibility
(psig) (psig) (psi-1) (1)
5000 4000 6.51 x 10 -6
4000 3000 7.01 x 10 -6
3000 2000 7.71 x 10 -6
2000 942 8.84 x 10 -6
(1) Mean compressibility = (V2-V1) / [(V1+V2)/2] x 1/(P1 - P2)
D.1
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Constant Composition Expansion at 203°F
Pressure Relative Density Instantaneous Y-Function (3)
(psig) Volume (1) (g cm-3) Compressibility
(psi-1 x 10-6) (2)
5000 0.9699 0.8245 6.31
4500 0.9730 0.8218 6.51
4000 0.9762 0.8191 6.74
3485 Reservoir pressure 0.9797 0.8162 7.01
3000 0.9831 0.8134 7.31
2500 0.9868 0.8104 7.69
2000 0.9907 0.8072 8.17
1500 0.9949 0.8037 8.77
1300 0.9967 0.8023 9.06
1100 0.9985 0.8008 9.38
1000 0.9994 0.8001 9.54
942 Saturation pressure 1.0000 0.7996
939 1.0011
935 1.0025
931 1.0039
927 1.0053
924 1.0064
920 1.0079
905 1.0136
885 1.0216
857 1.0335
806 1.0581 2.851
724 1.1071 2.756
610 1.2034 2.613
472 1.3995 2.417
337 1.7856 2.190
290 2.0199 2.098
248 2.3152 2.009
216 2.6268 1.935
193 2.9211 1.877
175 3.2102 1.829
159 3.5262 1.784
146 3.8370 1.746
135 4.1491 1.712
127 4.4114 1.686
(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
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Graphs of Constant Composition Expansion Data
Relative Volume vs Pressure
Y Function vs Pressure
0.965
0.970
0.975
0.980
0.985
0.990
0.995
1.000
1.005
0 1000 2000 3000 4000 5000 6000
Pressure (psig)
RelativeVolume,V/Vsat
0.000
0.500
1.000
1.500
2.000
2.500
3.000
0 100 200 300 400 500 600 700 800 900
Pressure (psig)
Y-Function
D.3
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Section E - Differential Vaporization (DV)
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Differential Vaporization at 203°F
Solution Relative Relative Deviation Gas Incremental
Pressure Gas-Oil Oil Total Density Factor Formation Gas Gravity
(psig) Ratio Volume Volume (g cm-3) (Z) Volume (Air = 1.000)
Rs(1) Bod(2) Btd(3) Factor (4)
942 262 1.216 1.216 0.7996 Saturation Pressure
800 238 1.207 1.295 0.8021 0.908 0.02089 0.823
600 205 1.193 1.474 0.8061 0.918 0.02797 0.851
400 168 1.177 1.878 0.8111 0.931 0.04208 0.904
200 121 1.156 3.239 0.8167 0.952 0.08309 1.049
100 87 1.135 6.057 0.8235 0.969 0.15838 1.281
0 0 1.065 0.8432 1.902
At 60°F = 1.000
Residual Oil Properties
API 25.9
(1) GOR in cubic feet of gas at 14.696 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 14.696 psia and 60°F.
E.1
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Graphs of Differential Vaporization
Solution Gas-Oil Ratio v Pressure
Relative Oil Volume v Pressure
0
50
100
150
200
250
300
0 100 200 300 400 500 600 700 800 900 1000
Pressure (psig)
Gas-OilRatio(scf/bbl)
1.000
1.050
1.100
1.150
1.200
1.250
0 100 200 300 400 500 600 700 800 900 1000
Pressure (psig)
RelativeOilVolume(V/Vr)
E.2
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Compositional Analysis of Differential Vaporization Gases to C11+
Sample I.D.
Test Stage 1 2 3 4 5 6
Stage Pressure (psig) 800 600 400 200 100 0
Component (Mole%)
H2 Hydrogen 0.00 0.00 0.00 0.00 0.00 0.00
H2S Hydrogen Sulphide 0.00 0.00 0.00 0.00 0.00 0.00
CO2 Carbon Dioxide 4.58 5.10 5.77 6.32 5.77 1.59
N2 Nitrogen 10.34 7.26 4.09 1.51 0.40 0.04
C1 Methane 66.37 65.34 61.73 49.42 30.89 4.33
C2 Ethane 7.42 8.70 10.83 14.63 17.87 9.64
C3 Propane 6.81 8.22 10.77 17.05 26.05 31.63
iC4 i-Butane 0.91 1.11 1.45 2.45 4.01 7.64
nC4 n-Butane 1.72 2.11 2.74 4.71 7.94 18.74
C5 Neo-Pentane 0.01 0.01 0.01 0.02 0.04 0.09
iC5 i-Pentane 0.59 0.68 0.77 1.26 2.32 7.72
nC5 n-Pentane 0.43 0.52 0.66 1.00 1.85 6.66
C6 Hexanes 0.37 0.42 0.53 0.73 1.35 5.69
M-C-Pentane 0.08 0.10 0.13 0.18 0.33 1.46
Benzene 0.00 0.01 0.01 0.02 0.03 0.16
Cyclohexane 0.04 0.05 0.06 0.09 0.17 0.69
C7 Heptanes 0.14 0.16 0.19 0.28 0.48 1.94
M-C-Hexane 0.04 0.05 0.06 0.08 0.14 0.53
Toluene 0.01 0.01 0.01 0.02 0.03 0.15
C8 Octanes 0.07 0.08 0.10 0.13 0.21 0.76
E-Benzene 0.00 0.00 0.01 0.01 0.01 0.05
M/P-Xylene 0.00 0.00 0.00 0.00 0.01 0.03
O-Xylene 0.00 0.00 0.00 0.00 0.00 0.02
C9 Nonanes 0.04 0.05 0.06 0.06 0.08 0.29
1,2,4-TMB 0.00 0.00 0.00 0.00 0.00 0.01
C10 Decanes 0.02 0.02 0.02 0.02 0.02 0.12
C11+ Undecanes plus 0.01 0.00 0.00 0.01 0.00 0.09
_____ _____ _____ _____ _____ _____
Totals : 100.00 100.00 100.00 100.00 100.00 100.00
Calculated Gas Properties
Gas Gravity 0.823 0.851 0.904 1.049 1.281 1.902
(Air = 1.000)
Note: 0.00 means less than 0.005.
E.3
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Compositional Analysis of Differential Vaporization Residue to C36+
C1 Methane 0.00 0.00
C2 Ethane 0.02 0.00
M-C-Pentane 1.30 0.40
Benzene 0.21 0.06
M-C-Hexane 1.57 0.56
Toluene 0.70 0.23
E-Benzene 0.71 0.27
O-Xylene 0.43 0.17
1,2,4-TMB 0.50 0.22
C10 Decanes 5.07 2.59
C36+ Hexatriacontanes plus 12.65 35.73_____ _____
Totals : 100.00 100.00
E.4
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Compositional Analysis of Differential Vaporization Residue to C36+
C7+ Mole% 92.55
C11+ Mole% 67.50
C20+ Mole% 34.25
C36+ Mole % 12.65
Density at 60°F (g cm-3) [Measured] 0.8983
API 25.9
E.5
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Differential Vaporization Data Converted to Production Separator Conditions
Oil Solution Formation Gas Formation
Pressure Density Gas/Oil Volume Volume
(psig) (g cm-3) (scf / bbl) Factor Factor
Rs(1) Bo(1) Bg(2)
5000 0.8244 1.128
4500 0.8218 1.132
4000 0.8191 1.135
3485 Reservoir pressure 0.8162 1.139
3000 0.8133 1.143
2500 0.8103 1.148
2000 0.8071 1.152
1500 0.8037 1.157
1300 0.8023 1.159
1100 0.8008 1.161
1000 0.8001 1.162
942 Saturation pressure 0.7996 191 1.163
800 0.8021 168 1.154 0.02089
600 0.8061 137 1.141 0.02797
400 0.8111 102 1.126 0.04208
200 0.8167 56 1.105 0.08309
100 0.8235 24 1.085 0.15838
Notes:
(1) Differential data corrected to surface separator conditions of :-
Stage 1 45 psig and 100°F
Stage 2 0 psig and 60°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 14.696 psia and 60°F.
E.6
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Section F - Separator Test Data
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Separator Test Data
Gas-Oil Gas-Oil Oil Formation Separation Gas Gravity
Pressure 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)
942 203 - 191 0.7996 1.163 Saturation Pressure
45 100 164 168 0.8736 1.027 1.040
0 60 23 23 0.8899 1.000 1.421
Residual Oil Properties **
API gravity 27.3 °
Note :
* Evolved gas collected and analyzed to C10+.
** Stocktank oil collected and analyzed to C36+.
(1) GOR in cubic feet of gas at 14.696 psia and 60°F per barrel of oil at indicated pressure and temperature.
(2) GOR in cubic feet of gas at 14.696 psia and 60°F per barrel of stocktank oil at 60°F.
(3) Volume of saturated oil at 942 psig and 203°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.
F.1
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Compositional Analysis of Separator Test Gases to C10+
Sample I.D.
Test Stage 1 2
Stage Pressure (psig) 45 0
Component (Mole%)
C1 Methane 49.54 17.98
C2 Ethane 12.92 18.20
C3 Propane 18.49 35.80
nC4 n-Butane 5.05 10.68
Benzene 0.02 0.02
Toluene 0.02 0.03
E-Benzene 0.00 0.00
O-Xylene 0.00 0.00
C10+ Decanes plus 0.02 0.01
_____ _____
Totals : 100.00 100.00
Calculated Gas Properties
Gas Gravity 1.040 1.421
(Air = 1.000)
Note: 0.00 means less than 0.005.
F.2
___________________________________________________________________________________________

Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Compositional Analysis of Stocktank Oil to C36+
C1 Methane 0.02 0.00
C2 Ethane 0.25 0.03
Benzene 0.24 0.07
Toluene 0.67 0.24
E-Benzene 0.67 0.28
O-Xylene 0.40 0.17
1,2,4-TMB 0.52 0.25
C10 Decanes 4.63 2.58
C36+ Hexatriacontanes plus 11.29 34.59_____ _____
Totals : 100.00 100.00
F.3
___________________________________________________________________________________________

Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Compositional Analysis of Stocktank Oil to C36+
C7+ Mole% 85.06
C11+ Mole% 60.28
C20+ Mole% 30.43
C36+ Mole % 11.29
Density at 60°F (g cm-3) [Measured] 0.8899
API 27.3
F.4
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Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Section G - Reservoir Fluid Viscosity Data
___________________________________________________________________________________________

Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Reservoir Fluid Viscosity Data at 203°F
Pressure Oil Calculated Oil/Gas
(psig) Viscosity Gas Viscosity Viscosity
(cP) (cP) (1) Ratio
5000 2.411
4000 2.225
3485 Reservoir pressure 2.129
3000 2.037
2000 1.846
1500 1.748
1000 1.648
942 Saturation pressure 1.637
800 1.826 0.0139 131.755
600 2.054 0.0133 154.039
400 2.259 0.0127 177.260
200 2.534 0.0119 213.858
100 2.831 0.0109 259.783
0 4.544
Reservoir Fluid Viscosity v Pressure at 203°F
(1) Calculated using the method of Lee, Gonzales and Eakin, JPT, Aug 1966.
0.00
0.50
1.00
1.50
2.00
2.50
3.00
3.50
4.00
4.50
5.00
0 1000 2000 3000 4000 5000 6000
Pressure (psig)
Viscosity(cP)
G.1
___________________________________________________________________________________________

Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Section H - Appendix
___________________________________________________________________________________________

Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
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 0.6954
Oxygen/(Argon) ** 31.999 1.1410 Cyclohexane * 84.16 0.7827
Nitrogen (Corrected) ** 28.013 0.8086 2MC6/23DMC5 * 100.20 0.6917
Methane ** 16.043 0.2997 11DMCYC5/3MC6 * 99.20 0.7253
Carbon Dioxide ** 44.010 0.8172 t13DMCYC5 * 98.19 0.7528
Ethane ** 30.070 0.3558 c13DMCYC5/3EC5 * 99.20 0.7262
Hydrogen Sulphide ** 34.080 0.8006 t12DMCYC5 * 98.19 0.7554
Propane ** 44.097 0.5065 Heptanes (nC7) * 100.20 0.6875
i-Butane ** 58.123 0.5623 22DMC6 * 114.23 0.6994
n-Butane ** 58.123 0.5834 MCYC6 * 98.19 0.7740
Neo-Pentane * 72.15 0.5968 ECYC5 * 98.19 0.7704
i-Pentane ** 72.150 0.6238 223TMC5/24&25DMC6 * 114.23 0.7060
n-Pentane ** 72.150 0.6305 ctc124TMCYC5 * 112.21 0.7511
22DMC4 * 86.18 0.6529 ctc123TMCYC5 * 112.21 0.7574
23DMC4/CYC5 * 78.16 0.7129 Toluene * 92.14 0.8734
2MC5 * 86.18 0.6572 Octanes (nC8) * 114.23 0.7063
3MC5 * 86.18 0.6682 E-Benzene * 106.17 0.8735
Hexanes (nC6) * 86.18 0.6631 M/P-Xylene * 106.17 0.8671
22DMC5 * 100.20 0.6814 O-Xylene * 106.17 0.8840
M-C-Pentane * 84.16 0.7533 Nonanes (nC9) * 128.26 0.7212
24DMC5 * 100.20 0.6757 Decanes *** 134 0.778
223TMC4 * 100.20 0.6947 Undecanes *** 147 0.789
Benzene * 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 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
___________________________________________________________________________________________

Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
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 0.789
Hyd. sulphide ** 34.080 0.8006 Dodecanes *** 161 0.800
Carbon Dioxide ** 44.010 0.8172 Tridecanes *** 175 0.811
Nitrogen ** 28.013 0.8086 Tetradecanes *** 190 0.822
Methane ** 16.043 0.2997 Pentadecanes *** 206 0.832
Ethane ** 30.070 0.3558 Hexadecanes *** 222 0.839
Propane ** 44.097 0.5065 Heptadecanes *** 237 0.847
i-Butane ** 58.123 0.5623 Octadecanes *** 251 0.852
n-Butane ** 58.123 0.5834 Nonadecanes *** 263 0.857
i-Pentane ** 72.150 0.6238 Eicosanes *** 275 0.862
n-Pentane ** 72.150 0.6305 Heneicosanes *** 291 0.867
Hexanes ** 86.177 0.6634 Docosanes *** 305 0.872
Me-cyclo-pentane * 84.16 0.7533 Tricosanes *** 318 0.877
Benzene * 78.11 0.8820 Tetracosanes *** 331 0.881
Cyclo-hexane * 84.16 0.7827 Pentacosanes *** 345 0.885
Heptanes ** 100.204 0.6874 Hexacosanes *** 359 0.889
Me-cyclo-hexane * 98.19 0.7740 Heptacosanes *** 374 0.893
Toluene * 92.14 0.8734 Octacosanes *** 388 0.896
Octanes ** 114.231 0.7061 Nonacosanes *** 402 0.899
Ethyl-benzene * 106.17 0.8735 Triacontanes *** 416 0.902
Meta/Para-xylene * 106.17 0.8671 Hentriacontanes *** 430 0.906
Ortho-xylene * 106.17 0.8840 Dotriacontanes *** 444 0.909
Nonanes ** 128.258 0.7212 Tritriacontanes *** 458 0.912
1-2-4-T-M-benzene * 120.19 0.8797 Tetratriacontanes *** 472 0.914
Decanes ** 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 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
___________________________________________________________________________________________

Piñuña-5 Well___________________________________________________________________________________________RFL 2010-36721
Report prepared by Report approved by
David McEvoy Richard M. (Rikki) Fyfe
Project Manager Operations Manager
PENCOR Advanced Fluid Studies PENCOR Advanced Fluid Studies
___________________________________________________________________________________________

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