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Reservoir Fluid Study
for
Hocol, S.A.
Ocelote-1 Well
RFL 0703054
Core Laboratories
Cra 39 Nro. 168-52, Bogot, 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 supplied
by the client to whom, and for whose exclusive and 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.
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Core Laboratories
Cra. 39 Nro. 168-52
Bogot, Colombia
Tel: 57 1 6740400
Web: http://www.corelab.com
Sincerely,CORE LABORATORIES
Simn Rodrguez
SupervisorReservoir Fluids Laboratory
January 30th, 2007
Perenco Colombia, LTD.
Bogota, Colombia.
Attention : Eng. Jina Martinez
Subject: Reservoir Fluid Study
Well: Candalay-1
Formation: Carbonera C7
Interval: 6,028' - 6,040'
File: 0603147
Dear Eng. Martinez:
Two wellhead samples from the subject well were collected on August 26th of 2006 by Core
Laboratories representatives and delivered to our fluid laboratory in Bogot for use in the
performance of a Reservoir Fluid Study. The samples were transported to the laboratory
whereupon sample validation and analysis commenced.
The final report of the Reservoir Fluid Study is presented in the following pages.
It has been a pleasure to perform this study for Perenco Colombia, LTD. Should any
questions arise or if we may be of further service in any way, please do not hesitate to
contact us.
April 20th, 2007
Hocol, S.A.
Bogot, Colombia
Attention : Eng. Larry Prent
Subject: Reservoir Fluid StudyWell: Ocelote-1
Formation:
Interval:
File: 0703054
Dear Sirs.:
Three bottomhole samples from the subject well were collected on December 16th of 2006
by Core Laboratories representatives and delivered to our fluid laboratory in Bogot for use
in the performance of a Reservoir Fluid Study.
Initial quality control checks were performed as soon as the samples were received and the
study proceded thereafter. Preliminary data was transmitted electronically during the
course of the study and the final report of this study is presented in the following pages.
It has been a pleasure to perform this study for Hocol, S.A. Should any questions arise or
if we may be of further service in any way, please do not hesitate to contact us.
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Hocol, S.A.
Ocelote-1 Well___________________________________________________________________________________________RFL 0703054
Table of Contents
Section A - Summary of Analysis Methods and PVT 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 for bottomhole samples..................................................................................... B.1
Summary of samples received...................................................................................................... B.2
Section C - Compositional Analysis of Bottomhole Reservoir Fluid
Compositional analysis of bottomhole sample to C36+................................................................ C.1-C.2
Section D- Constant Composition Expansion (CCE)
Constant composition expansion data at 207 F.......................................................................... D.1
Graph of constant composition expansion data at 207 F............................................................ D.2
Section E - Differential Vaporization
Differential vaporization data........................................................................................... E.1
Graphs from differential vaporization data....................................................................... E.2
Differential vaporization data converted to surface separator conditions........................ E.3-E.4
Section F - Reservoir Fluid Viscosity Data
Reservoir fluid viscosity data........................................................................................... F.1
Section G - Separator Test Data
Data from separator test 1............................................................................................... G.1
Compositional analysis of gas sample from separator test............................................. G.2
Data from separator test 2............................................................................................... G.3
Compositional analysis of gas sample from separator test............................................. G.4
Section H - Appendix
Data used in gas compositional calculations................................................................... H.1
Data used in liquid compositional calculations................................................................ H.2
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Section A - Summary of PVT Analysis Methods and Data
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Ocelote-1 Well___________________________________________________________________________________________RFL 0703054
Summary of Analyses Methods
Sample Validation
The bubble point pressure at ambient temperature and free water content of each bottomholesample were determined as initial quality checks. From this quality control, the measured bubble
point pressures of the samples showed good agreement with one another and very little free
water was measured.
Heat Treatment
The selected bottomhole fluid sample was heated to 200F prior to subsampling for laboratory
tests to avoid potential wax deposition problems.
Pressurized Fluid Composition
Approximately 30 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 toproduce 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 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 CompositionResidual/stocktank liquid composition were measured using a Varian 3400 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 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 for liquid samples 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 known composition. The resultant calibration data is checked statistically against previous
calibrations prior to performing analyses on unknown samples.
A.1
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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 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 physicallymeasure the molecular weight and density.
Constant Composition Expansion
A portion of the bottomhole fluid sample was charged to a high pressure visual cell at ambient
laboratory temperature. The sample was thermally expanded to the reservoir temperature and a
constant composition expansion was carried out during which the bubble point pressure at
reservoir temperature was determined. Pressure-volume data for the single phase and two
phase fluid were also measured. 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 VaporizationThis 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
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Summary of Analyses 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 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 in 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 stageseparation. 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.
A.3
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Section B - Summary of Samples Received and Validation Data
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Reported Well and Sampling Information
Reservoir and Well Information
Field......................................................................... OceloteWell.......................................................................... Ocelote-1Reservoir Fluid......................................................... Black OilFormation.................................................................Current Reservoir Pressure .................................... 1645 psiaReservoir Temperature............................................ 173 F
Installation................................................................ *DST.......................................................................... *Perforated Interval .................................................. *
Sampling Information
Date sampled........................................................... 16-Dec-06Time sampled ..........................................................Type of samples....................................................... BottomholeSampling company................................................... Core LaboratoriesSampling Depth....................................................... 4127 ft. MD
Choke....................................................................... *Status of well............................................................ Shut-in
Bottomhole pressure................................................ *Bottomhole temperature........................................... *
Wellhead pressure................................................... *Wellhead temperature.............................................. *
Separator pressure ................................................. *Separator temperature ............................................ *
Pressure base.......................................................... 14.7 psiaTemperature base ................................................... 60 F
Separator gas rate................................................... *Separator oil rate ..................................................... *Separator gas-Oil ratio............................................. *Water flowrate.......................................................... *Gas gravity (Air = 1)................................................. *Supercompressibility factor...................................... *H2S.......................................................................... *BS&W....................................................................... *API Oil Gravity ........................................................ *
Comments:* Data not provided to Core Laboratories
18:15 - 19:45 Hrs.
B.1
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Summary of Samples Received
Bottomhole Samples
LaboratorySample Cylinder Sampling :- Bubble point :- Free water SampleNumber Number Pressure Temp. Pressure Temp. drained Volume BSW
(psia) (F) (psig) (F) (cc) (cm3) (%)
1.1 59423D 178 67
1.2 896612C 240 71
1.3 818411 191 73
Notes:
Bottomhole Sample 1.3 was selected for compositonal analysis and PVT study.
B.2
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Section C - Compositional Analysis of Bottomhole Reservoir Fluid
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Compositional Analysis of Bottomhole Sample to C36 plus
Component Mole % Weight %
H2 Hydrogen 0.00 0.00
H2S Hydrogen Sulphide 0.00 0.00CO2 Carbon Dioxide 0.08 0.01N2 Nitrogen 0.10 0.01C1 Methane 7.00 0.42C2 Ethane 0.10 0.01C3 Propane 0.02 0.00iC4 i-Butane 0.04 0.01nC4 n-Butane 0.01 0.00C5 Neo-Pentane 0.00 0.00iC5 i-Pentane 0.17 0.05nC5 n-Pentane 0.04 0.01C6 Hexanes 0.95 0.31 M-C-Pentane 0.53 0.17 Benzene 0.03 0.01 Cyclohexane 0.23 0.07
C7 Heptanes 2.30 0.86 M-C-Hexane 2.06 0.75 Toluene 0.02 0.01
C8 Octanes 4.72 2.01 E-Benzene 0.35 0.14 M/P-Xylene 0.45 0.18 O-Xylene 0.16 0.06
C9 Nonanes 3.94 1.88 1,2,4-TMB 0.38 0.17
C10 Decanes 4.23 2.24C11 Undecanes 4.11 2.25C12 Dodecanes 3.94 2.37C13 Tridecanes 4.79 3.13C14 Tetradecanes 4.57 3.24
C15 Pentadecanes 4.81 3.69C16 Hexadecanes 4.11 3.40C17 Heptdecanes 3.75 3.31C18 Octadecanes 4.07 3.81C19 Nonadecanes 3.49 3.42C20 Eicosanes 3.14 3.22C21 Heneicosanes 2.80 3.03C22 Docosanes 2.51 2.86C23 Tricosanes 2.31 2.74C24 Tetracosanes 2.11 2.60C25 Pentacosanes 1.92 2.46C26 Hexacosanes 1.75 2.34C27 Heptacosanes 1.67 2.33C28 Octacosanes 1.55 2.24C29
Nonacosanes 1.48 2.21C30 Triacontanes 1.35 2.09C31 Hentriacontanes 1.21 1.94C32 Dotriacontanes 1.02 1.68C33 Tritriacontanes 0.93 1.60C34 Tetratriacontanes 0.81 1.42C35 Pentatriacontanes 0.72 1.30
C36+ Hexatriacontanes Plus 7.17 25.94 _____ _____
Totals : 100.00 100.00
Note: 0.00 means less than 0.005.
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C.1
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Compositional Analysis of Bottomhole Sample to C36 plus
Calculated Residue Properties
C7 plus Mole% 91.49
Molecular Weight (g mol-1) 291
Density at 60F (g cm-3) 0.9160
C11 plus Mole% 72.09Molecular Weight (g mol-1) 337
Density at 60F (g cm-3) 0.9384
C20 plus Mole% 34.45
Molecular Weight (g mol-1) 483
Density at 60F (g cm-3) 0.9986
C36 plus Mole % 7.17
Molecular Weight (g mol-1) 971
Density at 60F (g cm-3) 1.2073
Calculated Whole Sample Properties
Average mole weight (g mol-1) 268
Density at 60F (g cm-3) 0.9067
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C.2
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Section D- Constant Composition Expansion (CCE)
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Constant Composition Expansion at 173F
Single-phase Fluid Properties
Saturation pressure (bubble-point pressure) 167 psig
Thermal expansion factor of single phase fluid at 5000 psig
(Vol at 173F)/(Vol at 60F) 1.0490 vol / vol
Average single phase compressibility
(From 1630 psig to 167 psig) 5.73 x 10 -6 psi-1
Density at saturation pressure 0.8782 g cm-3
Mean Single-phase Compressibilities
Pressure Range MeanInitial Pressure Final Pressure Compressibility
(psig) (psig) (psi-1) (1)
5000 4000 4.41 x 10 -6
4000 3000 4.59 x 10 -6
3000 1630 4.91 x 10 -6
1630 167 5.73 x 10 -6
(1) Mean compressibility = (V2-V1) / [(V1+V2)/2] x 1/(P1 - P2)
D.1
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Constant Composition Expansion at 173F
Pressure Relative Density Instantaneous Y-Function (3)
(psig) Volume (1) (g cm-3) Compressibility(psi-1 x 10-6) (2)
5000 0.9762 0.8996 4.33
4000 0.9805 0.8957 4.49
3000 0.9850 0.8916 4.71
2000 0.9898 0.8873 5.01
1630 Reservoir pressure 0.9917 0.8856 5.17
1000 0.9950 0.8826 5.52
900 0.9955 0.8821 5.60
800 0.9961 0.8816 5.68
700 0.9967 0.8811 5.77
600 0.9973 0.8806 5.86
500 0.9978 0.8801 5.97
400 0.9984 0.8796 6.08300 0.9991 0.8790 6.20
200 0.9997 0.8785 6.28
167 Saturation pressure 1.0000 0.8782
160 1.0080
159 1.0092
156 1.0131
154 1.0159
152 1.0188
149 1.0235 4.685
140 1.0395 4.414
122 1.0843 3.906
101 1.1691 3.373
76 1.3546 2.829
49 1.7841 2.362
(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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Graphs of Constant Composition Expansion Data
Relative Volume vs Pressure
Y Function vs Pressure
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)
Rel
ativeVolume,V/Vsat
2.000
2.500
3.000
3.500
4.000
4.500
5.000
0 20 40 60 80 100 120 140 160
Pressure (psig)
Y-Function
D.3
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Section E - Differential Vaporization
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Differential Vaporisation at 173F
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)
167 20 1.054 1.054 0.8782 Saturation Pressure80 10 1.051 1.384 0.8790 0.994 0.18785 0.722
0 0 1.048 0.8798 0.786
At 60F = 1.000
Residual Oil Properties
Density of residual oil 0.9220 g cm-3 at 60F
API 21.8
(1) GOR in cubic feet of gas at 14.70 psia and 60F per barrel of residual oil at 60F.
(2) Volume of oil at indicated pressure and temperature per volume of residual oil at 60F.
(3) Volume of oil plus liberated gas at indicated pressure and temperature per volume of residual oil at 60F.
(4) Volume of gas at indicated pressure and temperature per volume at 14.70 psia and 60F.
E.1
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Graphs of Differential Vaporization
Solution Gas-Oil Ratio v Pressure
Relative Oil Volume v Pressure
0
5
10
15
20
25
0 20 40 60 80 100 120 140 160 180
Pressure (psig)
Gas
-OilR
atio(scf/bbl)
1.044
1.046
1.048
1.050
1.052
1.054
1.056
0 20 40 60 80 100 120 140 160 180
Pressure (psig)
Rel
ativeOilV
olume(V/Vr)
E.2
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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 0.8996 1.016
4000 0.8957 1.021
3000 0.8916 1.025
2000 0.8873 1.030
1630 Reservoir pressure 0.8856 1.032
1000 0.8826 1.036
900 0.8821 1.036
800 0.8816 1.037
700 0.8811 1.038
600 0.8806 1.038
500 0.8801 1.039
400 0.8796 1.039
300 0.8790 1.040
200 0.8783 1.041
167 Saturation pressure 0.8782 19 1.041
80 0.8790 9 1.038 0.18785
Notes:
(1) Differential data corrected to surface separator conditions of :-
Stage 1 70 psig and 85F
Stage 2 0 psig and 60F
Rs = Rsfb - (Rsdb - Rsd) x (Bofb / Bodb)
Bo = Bod x (Bofb/Bodb)
(2) Volume of gas at indicated pressure and temperature per volume at 14.70 psia and 60F.
E.3
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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 0.8996 1.017
4000 0.8957 1.022
3000 0.8916 1.026
2000 0.8873 1.031
1630 Reservoir pressure 0.8856 1.033
1000 0.8826 1.037
900 0.8821 1.037
800 0.8816 1.038
700 0.8811 1.039
600 0.8806 1.039
500 0.8801 1.040
400 0.8796 1.040
300 0.8790 1.041
200 0.8783 1.042
167 Saturation pressure 0.8782 19 1.042
80 0.8790 9 1.039 0.18785
Notes:
(1) Differential data corrected to surface separator conditions of :-
Stage 1 20 psig and 85F
Stage 2 0 psig and 60F
Rs = Rsfb - (Rsdb - Rsd) x (Bofb / Bodb)
Bo = Bod x (Bofb/Bodb)
(2) Volume of gas at indicated pressure and temperature per volume at 14.70 psia and 60F.
E.4
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Reservoir Fluid Viscosity Data at 173F
Pressure Oil Calculated Oil/Gas
(psig) Viscosity Gas Viscosity Viscosity
(cP) (cP) (1) Ratio
5000 14.226
4000 12.656
3000 11.201
2000 9.888
1630 Reservoir pressure 9.447
1000 8.767
500 8.314
167 Saturation pressure 8.07880 8.724 0.0125 698.3
0 9.490
Reservoir Fluid Viscosity v Pressure at 173F
0.00
2.00
4.00
6.00
8.00
10.00
12.00
14.00
16.00
0 1000 2000 3000 4000 5000 6000
Pressure (psig)
V
iscosity
(cP)
F.1
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Section G - Separator Test Data
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Data from Separator Test 1
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)
167 173 - 19 0.8782 1.041 Saturation Pressure
70 85 15 15 0.9049 1.017 0.677 *
0 60 4 4 0.9197 1.000 0.707
Residual Oil Properties
Density of residual oil 0.9197 g cm-3 at 60F
API 22.2
Note :
* Evolved gas collected and analysed to C11+.
(1) GOR in cubic feet of gas at 14.70 psia and 60F per barrel of oil at indicated pressure and temperature.
(2) GOR in cubic feet of gas at 14.70 psia and 60F per barrel of stocktank oil at 60F.
(3) Volume of saturated oil at 167 psig and 173F per volume of stocktank oil at 60F.
(4) Volume of oil at indicated pressure and temperature per volume of stocktank oil at 60F.
G.1
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Compositional Analysis of Separator Test Gas to C11+
Sampling Date 12-Apr-2007
Sample Description Ocelote-1 - 70psi Sep Test - First Stage Gas
Cylinder Number 818411
Sampling Conditions 70.0 psig @ 85.0F
Comments
Component Mole % Weight %
H2 Hydrogen 0.00 0.00
H2S Hydrogen Sulphide 0.00 0.00CO2 Carbon Dioxide 2.83 6.35N2 Nitrogen 2.40 3.43C1 Methane 89.56 73.28C2 Ethane 2.41 3.70C3 Propane 0.21 0.47iC4 i-Butane 0.36 1.07
nC4 n-Butane 0.05 0.15iC5 i-Pentane 0.30 1.10nC5 n-Pentane 0.04 0.15C6 Hexanes 0.29 1.27C7 Heptanes 0.35 1.79
C8 Octanes 0.87 5.07
C9 Nonanes 0.31 2.03
C10 Decanes 0.02 0.14C11+ Undecanes + 0.00 0.00
______ ______
Totals : 100.00 100.00Note: 0.00 means less than 0.005.
Calculated Residue Properties Mole Weight Density
(g mol-1) (g cm-3 @ 60F )
C7+ Heptanes plus 114.1 0.7067C8+ Octanes plus 118.2 0.7117
C10+ Decanes plus 134.0 0.7780
C11+ Undecanes plus - -
Calculated Whole Gas Properties
Real Relative Density 0.6789 (Air=1 @ 14.73 psia & 60F)
Whole Sample Mole Weight 19.61 g mol-1
Real Gas Density 0.8317 kg m-3 @ 15C
Ideal Gross Calorific Value 1092.6 BTU.ft-3 @ 14.73psia, 60F
Ideal Net Calorific Value 988.1 BTU.ft-3 @ 14.73psia, 60F
Pseudo Critical Press. 668.5 psia
Pseudo Critical Temp. 367.1 Rankine
Gas Compressibility Factor, Z 0.9971 @ 14.73 psia & 60F
Gas Viscosity 0.011 cP
GPM (C2+) 1.863GPM (C3+) 1.222
G.2
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Data from Separator Test 2
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)
167 173 - 19 0.8782 1.042 Saturation Pressure
20 85 17 17 0.9059 1.016 0.691 *
0 60 2 2 0.9201 1.000 0.706
Residual Oil Properties
Density of residual oil 0.9201 g cm-3 at 60F
API 22.1
Note :
* Evolved gas collected and analysed to C11+.
(1) GOR in cubic feet of gas at 14.70 psia and 60F per barrel of oil at indicated pressure and temperature.
(2) GOR in cubic feet of gas at 14.70 psia and 60F per barrel of stocktank oil at 60F.
(3) Volume of saturated oil at 167 psig and 173F per volume of stocktank oil at 60F.
(4) Volume of oil at indicated pressure and temperature per volume of stocktank oil at 60F.
G.3
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Compositional Analysis of Separator Test Gas to C11+
Sampling Date 12-Apr-2007
Sample Description Ocelote-1 - 20psi Sep Test - First Stage Gas
Cylinder Number 818411
Sampling Conditions 20.0 psig @ 85.0F
Comments
Component Mole % Weight %
H2 Hydrogen 0.00 0.00
H2S Hydrogen Sulphide 0.00 0.00CO2 Carbon Dioxide 2.91 6.40N2 Nitrogen 1.94 2.71C1 Methane 88.74 71.10C2 Ethane 3.17 4.76C3 Propane 0.26 0.57iC4 i-Butane 0.38 1.10
nC4 n-Butane 0.06 0.17iC5 i-Pentane 0.33 1.19nC5 n-Pentane 0.05 0.18C6 Hexanes 0.37 1.59C7 Heptanes 0.42 2.10
C8 Octanes 0.96 5.48
C9 Nonanes 0.34 2.18C10 Decanes 0.07 0.47C11+ Undecanes + 0.00 0.00
______ ______
Totals : 100.00 100.00Note: 0.00 means less than 0.005.
Calculated Residue Properties Mole Weight Density
(g mol-1) (g cm-3 @ 60F )
C7+ Heptanes plus 114.4 0.7084C8+ Octanes plus 118.7 0.7140
C10+ Decanes plus 134.0 0.7780
C11+ Undecanes plus - -
Calculated Whole Gas Properties
Real Relative Density 0.6936 (Air=1 @ 14.73 psia & 60F)
Whole Sample Mole Weight 20.02 g mol-1
Real Gas Density 0.8498 kg m-3 @ 15C
Ideal Gross Calorific Value 1120.9 BTU.ft-3 @ 14.73psia, 60F
Ideal Net Calorific Value 1014.4 BTU.ft-3 @ 14.73psia, 60F
Pseudo Critical Press. 668.9 psia
Pseudo Critical Temp. 372.0 Rankine
Gas Compressibility Factor, Z 0.9969 @ 14.73 psia & 60F
Gas Viscosity 0.011 cP
GPM (C2+) 2.258GPM (C3+) 1.414
G.4
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Section H - Appendix
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Data Used in Gas Compositional Calculations
Component Mole Weight Density Component Mole Weight Density(g mol-1) (g cm-3 at 60F) (g mol-1) (g cm-3 at 60F)
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 0.7060n-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.
** GP A 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
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Data Used in Oil Compositional Calculations
Component Mole Weight Density Component Mole Weight Density(g mol-1) (g cm-3 at 60F) (g mol-1) (g cm-3 at 60F)
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 0.872Me-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
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Report prepared by Report approved by
David McEvoy Simn RodrguezProject Manager SupervisorReservoir Fluid Laborator Reservoir Fluid Laborator