Reservoir Fluid Study for OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 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 12th, 2006
Occidental de Colombia. Bogota, Colombia. Attention : Eng. Aldo Caliz Subject: Well: Formation: Interval: File:
Reservoir Fluid Study Caricare-5 M2 9712'-9724' 0603116
Dear Sirs.: Two bottomhole samples and two wellhead samples from the subject well were collected on July 9th and July 10th of 2006 by Core Laboratories representatives and delivered to our fluid fluid laborato laboratory ry in Bogotá Bogotá for use in the performance performance of a Reserv Reservoir oir Fluid Fluid Study Study.. The samples samples were 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 denta ntall de Colo Colombi mbia. a. 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 Caricare-5 Well,_____________________________________ Form.: M2 RFL 0603116 ___________________________________ ________________ _____________________________________ ______________________________________ ___________________ Table of Contents Section A - Summary of PVT Methods and Data
Page
Summary Summary of analysis analysis methods....... methods................. ................... .................. ................... ................... .................. ................... ................... ............... ......
A.1-A.3 A.1-A.3
Summary 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 Bottomhole Fluid Sample to C36+ Compositiona Compositionall analysis analysis of bottomhole bottomhole fluid sample to C36+.......... C36+.................... ................... ................... .............. ....
C.1-C.2
Section D - Constant Composition Expansion Constant Constant composition composition expansion expansion at 200 °F................ °F......................... .................. ................... ................... ................... ................ ......
D.1-D.2
Graphs Graphs from consta constant nt compos compositio ition n expans expansion ion at 200 °F..... °F......... ........ ........ ........ ........ ........ ........ ........ ........ ........ ....... ...
D.3
Partial constant constant composition composition expansion expansion at 120 °F............... °F......................... ................... .................. ................... ............... .....
D.4-D.5
Partial constant constant composition composition expansion expansion at 86 °F................ °F......................... .................. ................... ................... ................ .......
D.6-D.7
Partial constant constant composition composition expansion expansion at laboratory laboratory ambient ambient temperature temperature (70 °F)....... °F).......
D.8-D.9
Section E - Differential Vaporization Differential Differential vaporizatio vaporization n data.......... data................... .................. .................. .................. .................. .................. .................. .................. .................. .........
E.1
Graphs from differential differential vaporization vaporization data............ data..................... .................. ................... ................... ................... ................... ............ ...
E.2
ompo ompos s t ona ona
na ys s o
eren erentt a
apor apor zat zat on
ases ases to
+... +..... .... .... .... .... .... .... .... .... .... .... .... .... .... ..
.
Composition Compositional al Analysis Analysis of Differential Differential Vaporizatio Vaporization n Residue Residue to C36+........... C36+.................... ................. ........
E.4-E.5 E.4-E.5
Differential Differential vaporizatio vaporization n data converted converted to surface surface separator separator conditions. conditions.......... .................. .............. .....
E.6-E.7 E.6-E.7
Section F - Bottomhole Fluid Viscosity Data Bottomhole Bottomhole fluid viscosity viscosity data.......... data................... .................. .................. .................. .................. .................. .................. .................. ............... ......
F.1
Graphs from bottomhole bottomhole fluid viscosity viscosity data............ data...................... ................... ................... ................... ................... ................. .......
F.2
Section G - Separator Test Data Separator Separator test 1................ 1......................... .................. .................. .................. .................. ................... ................... .................. .................. .................. ............. .... Compositional Compositional analysis analysis of gas sample from separator separator test 1.................. 1............................ .................... .............. .... Separator Separator test 2................ 2......................... .................. .................. .................. .................. ................... ................... .................. .................. .................. ............. .... Compositional Compositional 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...................................................................
H.1
Data used in liquid compositional calculations................................................................
H.2
________________________________________________________ _____________________________________ ______________________________________ ___________________________________ ________________ Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well,_____________________________________ Form.: M2 RFL 0603116 ___________________________________ ________________ _____________________________________ ______________________________________ ___________________
Section A - Summary of PVT Analysis Methods and Data
________________________________________________________ _____________________________________ ______________________________________ ___________________________________ ________________ Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well,_____________________________________ Form.: M2 RFL 0603116 ___________________________________ ________________ _____________________________________ ______________________________________ ___________________
Summary of Analysis Methods
Sample Validation The bubble point pressure at ambient temperature and free water content of each bottomhole sample were determined determined as initial initial quality checks. From this quality control, control, the measured bubble point pressures of the samples showed good agreement with one another and very little free water was measured. measured. The PVT study study proceede proceeded d using using the bottomhol bottomhole e sample samples s while while the wellhead wellhead samples were retained as backups. Heat Treatment The selected bottomhole fluid sample was heated to 200°F 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 separated into gas and oil phase. phase. The evolved gas and residual liquid were analyzed analyzed separate separately, ly, 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 hydrocarbon hydrocarbon gas with a known composition. composition. The resultant calibration calibration data is checked checked statisticall statistically y against previous calibrations calibrations prior to performing analyses on unknown samples. Liquid Composition Residual/sto Residual/stocktank cktank liquid composition composition were measured measured using a Varian Varian 3400 chromatograph. chromatograph. The gas chromatograph utilizes a cold on column, "sandwich injection" technique to ensure that a representati representative ve sample is injected and swept swept onto the column. The sample is run twice; first the origin original al fluid fluid and then fluid fluid spiked spiked with n-tetrad n-tetradeca ecane. ne. 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 correction prior to reporting the liquid compositio composition. n. The data obtained obtained from the gas chromatograph chromatograph is in weight weight %. Calculation Calculations s to mole% and the plus fractions fractions properties properties are described later. The chroma chromatogr tograph aph for liquid liquid sample samples s is checke checked d dail daily, y, using using a gravim gravimetri etric c n-para n-paraffin ffin mix containing containing a range of pure components components from C8 through C36 and a synthetic synthetic gas-oil mix (D2887) (D2887) with known composition. composition. The resultant calibration calibration data is checked statistically statistically against previous previous
________________________________________________________ _____________________________________ ______________________________________ ___________________________________ ________________ A.1 Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 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 bottomhole 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
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
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 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 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.
___________________________________________________________________________________________ A.3 Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Summary of PVT Data Constant Composition Expansion at Laboratory Ambient Temperature (70 °F) Saturation pressure (bubble-point)
289 psig
Constant Composition Expansion at 86 °F Saturation pressure (bubble-point)
301 psig
Constant Composition Expansion at 120 °F aturat on pressure
u
e-po nt
ps g
Constant Composition Expansion at 200 °F Saturation pressure (bubble-point)
412 psig
Average single phase compressibility (From 3735 psig to 412 psig)
7.42
Thermal expansion at 5000 psig (Vol at 200°F)/(Vol at 60°F)
x 10 -6 psi-1
1.0482 vol / vol
Differential Vaporization at 200 °F o ut on gas-o rat o at saturat on pressure
sc
Relative oil volume at saturation pressure
o res ua o at
1.130 vol / vol of residual oil at 60°F
Density at saturation pressure
0.7756 g cm-3
Bottomhole Fluid Viscosity at 200 °F scos ty at reservo r pressure
.
Viscosity at saturation pressure Separator Test Data Pressure (psig)
cent po se at
ps g
1.170 centipoise at 412 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 . 60 0
200 200
412
200
30 0
200 200
0.8504
Test 2 1.140
98 0.8534
___________________________________________________________________________________________ A.4 Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Section B - Summary of Samples Received and Validation Data
___________________________________________________________________________________________ Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Reported Well and Sampling Information Reservoir and Well Information Field................... .................. .................. .................. Caricare Well.......................................................................... Caricare-5 Reservoir Fluid......................................................... Black Oil Formation................................................................. M2 Current Reservoir Pressure .................................... 3750 psia Reservoir Temperature............................................ 200 °F Installation................................................................ * DST.......................................................................... * Perforated Interval .................. ................. ............... 9712'-9724' Sampling Information Date sampled........................................................... 9-Jul-06 & 10-Jul-06 Time sampled ......................................................... 15:15-16:40 & 08:50 Type of samples....................................................... Wellhead & Bottomhole Sampling company.................... .................. ............ Core Laboratories Sampling Depth................... ................. ................. . 8,000 ft Choke....................................................................... * Status of well............................................................ Shut-In Bottomhole pressure................................................ 3115 psia Bottomhole temperature.............. ............................ 210 °F 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
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Summary of Samples Received Bottomhole Samples
Sampling :Pressure Temp. (psia) (°F)
Laboratory Bubble point :Pressure Temp. (psig) (°F)
Sample Number
Cylinder Number
1.1
815666
3115
210
299
1.2
818424
3115
210
300
Free water drained (cc)
Sample Volume (cm3)
BSW (%)
75
Trace
560
0.0
75
Trace
540
0.0
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
896612C
415
95.8
NM
--
NM
500
NM
2.2
966951D
415
95.8
NM
--
NM
500
NM
Notes: NM = Not Measured Bottomhole Sample 1.2 was selected for compositonal analysis and PVT study.
___________________________________________________________________________________________ B.2 Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Section C - Compositional Analysis of Bottomhole Fluid Sample to C36+
___________________________________________________________________________________________ Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________ Compositional Analysis of Bottomhole 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 0.19 0.08 13.50 2.97 1.91 0.54 1.10 0.00 0.81 0.91 2.50 0.78 0.09 0.39 3.60 1.67 0.47 5.25 0.41 0.52 0.21 4.87 0.44 5.27 5.03 4.40 4.58 4.12 3.55 2.95 2.68 2.70 2.32 1.91 1.75 1.55 1.38 1.25 1.17 0.98 0.92 0.86 0.78 0.69 0.62 0.49 0.45 0.39 0.35 3.65 _____
Weight % 0.00 0.00 0.05 0.01 1.22 0.50 0.47 0.18 0.36 0.00 0.33 0.37 1.22 0.37 0.04 0.18 2.04 0.92 0.24 3.38 0.24 0.31 0.13 3.52 0.30 4.23 4.17 3.99 4.52 4.42 4.13 3.69 3.59 3.83 3.44 2.96 2.87 2.66 2.48 2.34 2.28 1.99 1.94 1.88 1.76 1.62 1.52 1.23 1.17 1.04 0.97 12.90 _____
___________________________________________________________________________________________ Totals : 100.00 100.00 C.1 Core Laboratories Note: 0.00 means less than 0.005. Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________ Compositional Analysis of Bottomhole Sample to C36 plus
Calculated Residue Properties C7 plus
Mole % Mole Weight (g mol-1) Density at 60°F (g cm-3)
75.49 224 0.8397
C11 plus
Mole % Mole Weight (g mol-1) Density at 60°F (g cm-3)
51.52 273 0.8655
C20 plus
Mole % Mole Weight (g mol-1) Density at 60°F (g cm-3)
19.19 402 0.9011
C36 plus
Mole % Molecular Weight (g mol-1) Density at 60°F (g cm-3)
3.65 624 0.9372
Calculated Whole Sample Properties Average mole weight (g mol-1) Density at 60°F (g cm-3)
177 0.8073
___________________________________________________________________________________________ C.3 Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Section D - Constant Composition Expansion (CCE)
___________________________________________________________________________________________ Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Constant Composition Expansion at 200°F Single-phase Fluid Properties Saturation pressure (bubble-point pressure)
412 psig
Thermal expansion factor of single phase fluid at 5000 psig (Vol at 200°F)/(Vol at 60°F) Average single phase compressibility (From 3735 psig to 412 psig)
1.0482 vol / vol
7.42 x 10 -6 psi-1
Density at saturation pressure
0.7756 g cm-3
Mean Single-phase Compressibilities Pressure Range Initial Pressure (psig)
Final Pressure (psig)
Mean Compressibility (psi-1) (1)
5000
3735
6.92
x 10 -6
3735
3000
6.99
x 10 -6
3000
2000
7.13
x 10 -6
2000
500
7.75
x 10 -6
500
412
8.88
x 10 -6
(1) Mean compressibility = (V2-V1) / [(V1+V2)/2] x 1/(P1 - P2)
___________________________________________________________________________________________ D.1 Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Constant Composition Expansion at 200°F Pressure (psig)
Relative Volume (1)
Density (g cm-3)
Instantaneous Compressibility (psi-1 x 10-6) (2)
5000 4000 3735 3000 2000 1000 900 800 700 600 500 412 411 410 409 406 405 404 400 376 362 321 257 196 157 121 92
0.9671 0.9738 0.9754 0.9807 0.9877 0.9951 0.9959 0.9967 0.9975 0.9984 0.9992 1.0000 1.0010 1.0019 1.0029 1.0058 1.0068 1.0078 1.0119 1.0386 1.0562 1.1191 1.2681 1.5212 1.8034 2.2441 2.8663
0.8020 0.7965 0.7952 0.7909 0.7853 0.7795 0.7788 0.7782 0.7776 0.7769 0.7763 0.7756
6.87 6.92 6.94 7.03 7.27 7.91 8.03 8.17 8.34 8.55 8.81
Reservoir pressure
Saturation pressure
Y-Function (3)
2.361 2.275 2.128 1.967 1.848 1.723 1.606
(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 Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Graphs of Constant Composition Expansion Data Relative Volume vs Pressure
1.000
0.995
t 0.990 a s V / V , e 0.985 m u l o V 0.980 e v i t a l e 0.975 R 0.970
0.965 0
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
Pressure (psig)
Y Function vs Pressure
2.400 2.300 2.200 2.100
n o i t 2.000 c n u 1.900 F Y 1.800 1.700 1.600 1.500 0
50
100
150
200
250
300
350
Pressure (psig)
___________________________________________________________________________________________ D.3 Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Constant Composition Expansion at 120°F Single-phase Fluid Properties Saturation pressure (bubble-point pressure)
332 psig
Thermal expansion factor of single phase fluid at 5000 psig (Vol at 120°F)/(Vol at 60°F) Average single phase compressibility (From 3735 psig to 332 psig)
1.0109 vol / vol
5.71 x 10 -6 psi-1
Mean Single-phase Compressibilities Pressure Range Initial Pressure (psig)
Final Pressure (psig)
Mean Compressibility (psi-1) (1)
5000
3735
5.10
x 10 -6
3735
3000
5.24
x 10 -6
3000
2000
5.46
x 10 -6
2000
500
6.00
x 10 -6
500
332
6.64
x 10 -6
(1) Mean compressibility = (V2-V1) / [(V1+V2)/2] x 1/(P1 - P2)
___________________________________________________________________________________________ D.4 Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Constant Composition Expansion at 120°F Pressure (psig)
Relative Volume (1)
Instantaneous Compressibility (psi-1 x 10-6) (2)
5000 4000 3735 3000 2000 1000 900 800 700 600 500 400 332 329
0.9744 0.9794 0.9806 0.9845 0.9899 0.9957 0.9963 0.9970 0.9976 0.9982 0.9989 0.9995 1.0000
5.05 5.14 5.18 5.32 5.62 6.12 6.19 6.27 6.35 6.45 6.55 6.66
Reservoir pressure
Saturation pressure
327 325 324 323
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.
___________________________________________________________________________________________ D.5 Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Constant Composition Expansion at 86°F Single-phase Fluid Properties Saturation pressure (bubble-point pressure)
301 psig
Thermal expansion factor of single phase fluid at 5000 psig (Vol at 86°F)/(Vol at 60°F) Average single phase compressibility (From 3735 psig to 301 psig)
1.0026 vol / vol
4.58 x 10 -6 psi-1
Mean Single-phase Compressibilities Pressure Range Initial Pressure (psig)
Final Pressure (psig)
Mean Compressibility (psi-1) (1)
5000
3735
4.20
x 10 -6
3735
3000
4.31
x 10 -6
3000
2000
4.44
x 10 -6
2000
500
4.84
x 10 -6
500
301
4.34
x 10 -6
(1) Mean compressibility = (V2-V1) / [(V1+V2)/2] x 1/(P1 - P2)
___________________________________________________________________________________________ D.6 Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Constant Composition Expansion at 86°F Pressure (psig)
Relative Volume (1)
Instantaneous Compressibility (psi-1 x 10-6) (2)
5000 4000 3735 3000 2000 1000 900 800 700 600 500 400 301 300
0.9792 0.9833 0.9843 0.9875 0.9919 0.9966 0.9971 0.9976 0.9981 0.9986 0.9991 0.9997 1.0000
4.15 4.24 4.26 4.35 4.54 4.92 4.98 5.06 5.15 5.26 5.40 5.59
Reservoir pressure
Saturation pressure
298 296 294 292
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)
___________________________________________________________________________________________ D.7 Core Laboratories Bogotá, Colombia
OCCIDENTAL DE COLOMBIA Caricare-5 Well, Form.: M2 RFL 0603116 ___________________________________________________________________________________________
Constant Composition Expansion at 70°F Single-phase Fluid Properties Saturation pressure (bubble-point pressure)
289 psig
Thermal expansion factor of single phase fluid at 5000 psig (Vol at 70°F)/(Vol at 60°F) Average single phase compressibility (From 3735 psig to 289 psig)
1.0000 vol / vol
4.79 x 10 -6 lpc-1
Mean Single-phase Compressibilities Pressure Range Initial Pressure (psig)
Final Pressure (psig)
Mean Compressibility (psi-1) (1)
5000
3735
3.93
x 10 -6
3735
3000
4.12
x 10 -6
3000
2000
4.35
x 10 -6
2000
500
4.99
x 10 -6
500
289
7.90
x 10 -6
(1) Mean compressibility = (V2-V1) / [(V1+V2)/2] x 1/(P1 - P2)
___________________________________________________________________________________________ D.8 Core Laboratories Bogotá, Colombia
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Constant Composition Expansion at 70°F Pressure (psig)
Relative Volume (1)
Instantaneous Compressibility (psi-1 x 10-6) (2)
5000 4000 3735 3000 2000 1000 900 800 700 600 500 400 300 289
0.9787 0.9826 0.9835 0.9866 0.9909 0.9956 0.9961 0.9967 0.9972 0.9978 0.9983 0.9989 0.9995 1.0000
3.84 3.99 4.04 4.20 4.52 5.12 5.22 5.33 5.46 5.62 5.80 6.04 6.40
Reservoir pressure
Saturation pressure
285 283 281 280 279
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)
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Section E - Differential Vaporization (DV)
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Differential Vaporization at 200°F
Pressure (psig)
Solution Gas-Oil Ratio Rs(1)
Relative Oil Volume Bod(2)
Relative Total Volume Btd(3)
412 300 150 0
113 92 63 0
1.130 1.123 1.107 1.072
1.130 1.341 2.109
At 60°F =
Density (g cm-3)
Deviation Factor (Z)
0.7756 0.7775 0.7845 0.7955
0.975 0.988
Gas Formation Volume Factor (4)
Incremental Gas Gravity (Air = 1.000)
Saturation Pressure 0.05779 0.689 0.11192 0.765 1.193
1.000
Residual Oil Properties Density of residual oil API
0.8524
g cm-3 at 60°F
34.3
(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.
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Graphs of Differential Vaporization Solution Gas-Oil Ratio v Pressure
120 100 l b b . s e r / f c s , o i t a R l i O s a G
80 60 40
20 0 0
40
80
120
160
200
240
280
320
360
400
440
320
360
400
440
Pressure, psig
Relative Oil Volume v Pressure 1.140
r 1.120 V / V , e m u l o V 1.100 l i O e v i t a l e R1.080
1.060 0
40
80
120
160
200
240
280
Pressure, psig
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Compositional Analysis of Differential Vaporization Gases to C11+ Sample I.D. Test Stage Stage Pressure (psig)
1 300
2 150
3 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 1.15 1.53 1.51 0.46 0.28 0.13 82.95 76.07 47.84 10.64 12.78 17.31 2.81 5.30 12.81 0.50 0.79 3.11 0.38 1.20 5.06 0.11 0.30 3.06 0.19 0.39 2.52 0.28 0.57 3.06 0.25 0.36 2.02 0.08 0.21 0.89 0.14 0.18 0.67 0.06 0.04 0.00 0.00 0.00 0.00 _____ _____ _____ 100.00 100.00 100.00
Calculated Gas Properties Gas Gravity (Air = 1.000)
0.689
0.765
1.193
Note: 0.00 means less than 0.005.
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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 0.14 0.22 0.35 0.26 0.75 0.66 0.85 2.86 5.84 9.00 7.25 7.01 6.16 5.40 5.63 5.07 4.41 3.69 3.39 3.39 2.93 2.42 2.21 1.96 1.75 1.59 1.49 1.25 1.17 1.08 0.98 0.88 0.79 0.62 0.57 0.49 0.45 5.04 _____ 100.00
Weight % 0.00 0.00 0.00 0.00 0.01 0.03 0.07 0.07 0.20 0.22 0.28 1.13 2.57 4.50 4.12 4.51 4.15 3.99 4.52 4.42 4.17 3.76 3.69 3.90 3.54 3.05 2.95 2.74 2.55 2.41 2.35 2.05 2.00 1.93 1.81 1.67 1.56 1.27 1.20 1.07 1.00 14.54 _____ 100.00
Note: 0.00 means less than 0.005.
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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)
93.91 227 0.8421
C11+
Mole% Molecular Weight (g mol-1) Density at 60°F (g cm-3)
64.81 277 0.8671
C20+
Mole% Molecular Weight (g mol-1) Density at 60°F (g cm-3)
24.74 407 0.9022
C36+
Mole % Molecular Weight (g mol-1) Density at 60°F (g cm-3)
5.04 629 0.9375
Calculated Whole Sample Properties Average mole weight (g mol-1) Density at 60°F (g cm-3) [Measured] API
218 0.8524 34.3
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Differential Vaporization Data Converted to Production Separator Conditions
Pressure (psig)
Oil Density (g cm-3)
5000 4000 3735 3000 2000 1000 900 800 700 600 500 412 300 150
0.8019 0.7963 0.7947 0.7910 0.7851 0.7792 0.7787 0.7782 0.7775 0.7767 0.7759 0.7756 0.7775 0.7845
Reservoir pressure
Saturation pressure
Solution Gas/Oil (scf / bbl) Rs(1)
Formation Volume Factor Bo(1)
Gas Formation Volume Factor Bg(2)
97 76 46
1.102 1.109 1.112 1.117 1.125 1.134 1.134 1.135 1.136 1.137 1.139 1.139 1.132 1.116
0.05779 0.11192
Notes: (1) Differential data corrected to surface separator conditions of :Stage 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.
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Differential Vaporization Data Converted to Production Separator Conditions
Pressure (psig)
Oil Density (g cm-3)
5000 4000 3735 3000 2000 1000 900 800 700 600 500 412 300 150
0.8019 0.7963 0.7947 0.7910 0.7851 0.7792 0.7787 0.7782 0.7775 0.7767 0.7759 0.7756 0.7775 0.7845
Reservoir pressure
Saturation pressure
Solution Gas/Oil (scf / bbl) Rs(1)
Formation Volume Factor Bo(1)
Gas Formation Volume Factor Bg(2)
98 77 47
1.103 1.110 1.113 1.118 1.126 1.135 1.135 1.136 1.137 1.138 1.140 1.140 1.133 1.117
0.05779 0.11192
Notes: (1) Differential data corrected to surface separator conditions of :Stage 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.
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Section F - Bottomhole Fluid Viscosity Data
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Bottomhole Fluid Viscosity Data at 200°F Pressure (psig)
Oil Viscosity (cP)
5000 4000 3735 3000 2000 1000 600 412 300 150 0
1.748 1.615 1.584 1.484 1.357 1.236 1.190 1.170 1.259 1.364 1.751
Reservoir pressure
Saturation pressure
Calculated Gas Viscosity (cP) (1)
Oil/Gas Viscosity Ratio
0.0134
94
0.0129
105.9
(1) Calculated using the method of Lee, Gonzales and Eakin, JPT, Aug 1966.
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Graphs of Bottomhole Fluid Viscosity Data at 200°F
Oil Viscosity Vs Pressure
1.800 1.700 1.600 s P 1.500 c , y t i s 1.400 o c s i v l 1.300 i O
1.200 1.100 1.000 0
40
80
120
160
200
240
280
320
360
400
440
Pressurre, psig
Single-phase Fluid Viscosity Vs Pressure
1.800
s P 1.600 c , y t i s o c s i V 1.400 e s a h p e l g n i 1.200 S
1.000 0
1000
2000
3000
4000
5000
Pressurre, psig
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Section G - Separator Test Data
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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) 1.139
412
200
-
97
0.7756
60 0
200 200
76 14
82 15
0.7908 0.7933
Separation Gas Gravity Volume of flashed gas Factor (Air = 1.000) (4) Saturation Pressure 1.082 1.072
1.025 * 1.515
Residual Oil Properties Density of residual oil API
0.8504
g cm-3 at 60°F
34.7
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 412 psig and 200°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.
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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 :
18-Sep-2006 Caricare-5 - 60psi Sep Test - First Stage Gas 818424 60.0 psig @ 200.0°F Mole % 0.00 0.00 2.35 0.67 65.46 13.29 7.54 1.96 2.53 1.29 0.92 1.59 1.23 0.75 0.29 0.11 0.02 ______ 100.00
Weight % 0.00 0.00 3.79 0.69 38.54 14.66 12.20 4.18 5.39 3.41 2.44 5.03 4.52 3.14 1.36 0.54 0.11 ______ 100.00
Mole Weight (g mol-1) 109.9 120.1 136.0 147.0
Density (g cm-3 @ 60°F ) 0.7038 0.7188 0.7798 0.7890
Note: 0.00 means less than 0.005.
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+)
0.9474 27.26 1.1609 1544.9 1409.4 656.5 453.0 0.9934 0.012 9.662 6.123
(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
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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) 1.140
412
200
-
98
0.7756
30 0
200 200
84 7
91 7
0.7945 0.7965
Separation Gas Gravity Volume of flashed gas Factor (Air = 1.000) (4) Saturation Pressure 1.078 1.071
1.222 * 1.725
Residual Oil Properties Density of residual oil API
0.8534
g cm-3 at 60°F
34.1
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 412 psig and 200°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.
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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 :
18-Sep-2006 Caricare-5 - 30psi Sep Test - First Stage Gas 818424 30.0 psig @ 200.0°F Mole % 0.00 0.00 2.31 0.64 59.15 13.82 8.83 2.49 3.37 1.84 1.39 2.33 1.84 1.21 0.49 0.24 0.05 ______ 100.00
Weight % 0.00 0.00 3.31 0.58 30.89 13.52 12.67 4.71 6.37 4.32 3.26 6.53 6.00 4.50 2.05 1.05 0.24 ______ 100.00
Mole Weight (g mol-1) 111.0 120.9 136.2 147.0
Density (g cm-3 @ 60°F ) 0.7063 0.7214 0.7800 0.7890
Note: 0.00 means less than 0.005.
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+)
1.0704 30.73 1.3121 1732.8 1584.7 646.4 482.7 0.9912 0.011 11.964 8.284
(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
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Section H - Appendix
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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.
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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.
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