summer internship report at ril
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Aman AroraSummer Trainee
Reservoir Management GroupRIL
Coring Operations
Laboratory Analysis
Hydraulic Unitization
Estimation of Water Saturation from Capillary Pressure
Generation of Relative Permeability Curve(s) from Capillary Pressure
Conventional Coring ( while drilling)◦ Conventional Core
No sleeve
Aluminum sleeve
Rubber/Plastic sleeve
◦ Sponge Core
◦ Gel Core
◦ Pressure core
Sidewall Coring ( post-drilling)◦ Percussion
◦ Rotary
CT scan Whole Core
GEOLOGIST
Photography
Minipermeability
RESERVOIR ENGG
DS plugs
Plugs
PreservationTo
Laboratory
This includes all the experiments and test procedures on core samples, and the data/results collected.
The two major categories of core analysis or experiments are:◦ conventional or routine core analysis,
◦ special core analysis.
This yields the most basic data about the reservoir. This includes the following:
• UV PhotographyPresence of
Hydrocarbons
• Photography/ Visual Observation Lithology
• Porosity MeasurementStorage Capacity
• Permeability MeasurementFlow Ability
• Water Saturation (Dean Stark)
• Hydrocarbon Saturation (Distillation)Saturation
These are more complex and the data furnished are of wider diversity.
They will require longer core preparation and testing times and more specialized and expensive equipment
Some common SCAL experiments and data are listed in the following table.
Property Test/Experiment
Relative Permeability Steady State Rel Perm
Unsteady State Rel Perm
Capillary Pressure Centrifuge
Porous Plate Technique
Mercury Injection
Pore Throat Size Distribution Mercury Injection
Wettabilty Amott’s Index
USBM Index
Mineral Composition X-Ray Diffraction
ICP
Thin Section Plate Photography
Semi Electron Microscope
CEC Wet Chemistry / Ion Exchange
Technique
Acid Solubility Acid Solubility Test
Grain Size Distribution Sieve Analysis
Laser Particle Size Analysis
Electrical Properties Laboratory Measurement
Rock Strength and properties Triaxial Static/Dynamic Test
Scratch Testing
Pressure Dependence of k, φ NOB Pressure Test
Interfacial Tension IFT Test/ Contact Angle
Fines Migration Critical Velocity Test
Rock properties vary widely in reservoirdepending on sedimentation, diagenesis etc.
Such variations affect reservoir storage andflow behavior, and thus its study.
Reservoir characterization is a prerequisitefor efficient development and management ofthese reservoirs
Reservoir description can be defined as theintegration of microscopic, mesoscopic andmacroscopic scales of data to compilereservoir zonation that accurately describesreservoir and reservoir dynamics.
i.e To discretize the reservoir into subunitssuch as layers and grid blocks and to assignrepresentative values of all petrophysicalparameters to each unit.
Ebanks (1987) defined hydraulic flow units as “amappable portion of the reservoir within whichgeological and petrophysicalproperties, controlling the flow of fluids, areconsistent and predictably different from theproperties of other reservoir rock portion”.
Hydraulic unit are defined by:
1. Mineralogy (type, abundance, morphology, andlocation relative to pore throat)
2. Texture (grain size, grainshape, sorting, packing)
Flow Zone Indicator (FZI) method classifiessection based on their pore throatcharacteristics
Process:◦ Calculate Reservoir Quality Index (RQI)
◦ Calculate φz (ratio of Pore Volume to Grain Volume)
◦ Calculate FZI
◦ Taking a suitable FZI interval, different HU aredecided
◦ On the graph of Log RQI Vs Log φz , all samples ofone HU lie on a straight line of unit slope.
◦ Each HU is allotted a color for easy identification.
◦ HU zonation is supported by other evidence likelithology, LPSA etc.
Sample Number
Core Ambient He Gas Horizontal Emp. Klink. Perm Grain
Depth Porosity Perm. 400 psig at 400 psig Density
(m) (% of Vb) (mD) (mD) (g/ml)
11 3198.83 11.9 28.3 23.8 2.91
16 3200.78 22.2 11.0 8.77 2.66
18 3201.51 18.4 0.71 0.48 2.74
DS1 3202.47 26.7 53.2 46.4 2.69
22 3203.97 31.5 2105 2022 2.68
DS2 3205.55 29.3 2799 2698 2.69
28 3206.03 24.0 124 114 2.70
32 3207.23 24.2 361 352 2.66
DS3 3209.30 27.4 1302 1245 2.68
DS4 3212.82 24.7 1435 1373 2.83
46 3213.58 12.6 0.43 0.28 2.67
48 3214.28 30.0 227 216 2.67
DS5 3215.37 23.7 2181 2096 2.71
DS8 3227.81 7.4 0.07 0.04 2.88
DS9 3228.31 31.6 4531 4407 2.74
69 3229.32 27.7 768 733 2.66
72 3230.37 28.1 737 703 2.69
74 3231.02 22.1 31.4 26.5 2.68
75 3232.30 27.0 478 455 2.69
78 3234.29 28.4 1701 1631 2.67
80 3235.10 26.6 3524 3410 2.69
DS11 3236.99 27.8 3560 3445 2.69
85 3237.55 22.7 65.9 58.2 2.65
87 3238.40 15.9 0.74 0.50 3.25
DS12 3239.24 23.4 21.5 17.8 2.66
91 3240.70 25.8 656 625 2.67
93 3241.40 23.4 30.6 25.9 2.67
Sample
Number
Core Ambient He Emp. Klink. Perm Grain frac RQI φz FZI
Depth Porosity at 400 psig Density poro avg perm avg poro LithoogyHU (m) (% of Vb) (mD) (g/ml)
1 97 3245.18 23.6 13583 2.69 0.24 7.53 0.309 24.407coarse1 159 3288.39 25.5 13231 2.67 0.26 7.15 0.343 20.854coarse1 DS42 3299.98 26.0 13433 2.67 0.26 7.13 0.352 20.268coarse1 DS40 3293.70 26.7 12530 2.67 0.27 6.81 0.364 18.716coarse1 DS39 3292.58 23.4 5363 2.66 0.23 4.75 0.305 15.565coarse1 HS3 3215.86 27.4 9463 2.71 0.27 5.84 0.377 15.503coarse1 83 3235.68 27.2 9279 2.67 0.27 10249.19 25.24 5.79 0.375 15.472coarse3 HS5 3226.10 23.0 1666 2.74 0.23 2.67 0.298 8.971coarse3 186 3309.33 28.0 3278 2.69 0.28 3.39 0.390 8.710coarse3 DS9 3228.31 31.6 4407 2.74 0.32 3.71 0.461 8.048coarse3 DS29 3283.20 28.3 2850 2.69 0.28 3.15 0.395 7.965fine3 DS2 3205.55 29.3 2698 2.69 0.29 3.01 0.415 7.249coarse3 129 3267.40 22.7 1022 2.67 0.23 2.11 0.293 7.197coarse3 DS4 3212.82 24.7 1373 2.83 0.25 2.34 0.328 7.136coarse3 154 3284.51 26.1 1561 2.67 0.26 2.43 0.352 6.894fine3 DS27 3278.77 24.3 1174 2.68 0.24 2.18 0.321 6.804coarse3 147 3279.20 25.5 1398 2.69 0.26 2.32 0.342 6.788coarse3 94 3242.14 28.8 2038 2.67 0.29 2.64 0.405 6.521coarse3 149 3280.78 25.6 1283 2.67 0.26 2.22 0.344 6.467medium3 DS13 3241.95 24.2 906 2.69 0.24 1.92 0.319 6.017coarse3 78 3234.29 28.4 1631 2.67 0.28 1900.73 26.08 2.38 0.396 6.014coarse6 16 3200.78 22.2 8.77 2.66 0.22 0.20 0.285 0.691fine6 DS19 3258.59 20.7 6.73 2.68 0.21 0.18 0.261 0.685fine6 135 3271.64 16.8 3.24 2.66 0.17 0.14 0.202 0.683fine6 DS17 3251.45 25.0 4.82 2.69 0.25 6.99 20.58 0.14 0.333 0.414fine7 46 3213.58 12.6 0.28 2.67 0.13 0.05 0.145 0.323fine7 DS8 3227.81 7.4 0.04 2.88 0.07 0.02 0.080 0.296lami7 87 3238.40 15.9 0.50 3.25 0.16 0.06 0.188 0.296clay7 137 3272.79 16.4 0.53 2.65 0.16 0.06 0.196 0.286fine7 DS37 3291.30 8.4 0.05 2.66 0.08 0.02 0.091 0.258fine7 18 3201.51 18.4 0.48 2.74 0.18 0.05 0.225 0.226fine7 114 3260.14 16.9 0.35 2.63 0.17 0.05 0.203 0.222fine7 DS43 3304.00 14.6 0.21 2.74 0.15 0.04 0.171 0.222silty7 DS21 3265.74 9.2 0.04 2.67 0.09 0.02 0.102 0.214fine7 HS1 3201.13 17.0 0.05 3.03 0.17 0.02 0.205 0.081fine7 DS22 3267.60 8.6 0.005 2.71 0.09 0.22 12.91 0.01 0.094 0.078
-2.5
-2
-1.5
-1
-0.5
0
0.5
1
1.5
-1.8 -1.6 -1.4 -1.2 -1 -0.8 -0.6 -0.4 -0.2 0
log R
QI
log φz
FZI
1
2
3
4
5
6
7
y = 0.029x3.970
R² = 0.415
y = 0.019x3.766
R² = 0.637
y = 0.018x3.538
R² = 0.656
y = 0.000x4.418
R² = 0.824
y = 0.001x3.331
R² = 0.868
y = 0.001x2.689
R² = 0.641
y = 4E-05x3.192
R² = 0.552
0.001
0.01
0.1
1
10
100
1000
10000
100000
0 5 10 15 20 25 30 35
K (
mD
)
PHI (%)
1
2
3
4
5
6
7
Power (1)
Power (2)
Power (3)
Power (4)
Power (5)
Power (6)
Power (7)
HU FZI Developed Correlation Average Average
Range K-φ Coefficient K φ
Correlation (md) (%)
1 >15.00 k = 0.0298φ3.9704 R² = 0.4158 10249.19 25.2
2 9.00-15.00 k = 0.0197φ3.7662 R² = 0.6377 2932.46 23.8
3 6.00-9.00 k = 0.018φ3.5385 R² = 0.6566 1900.73 26.1
4 4.00-6.00 k = 0.0004φ4.4188 R² = 0.8243 909.92 26.4
5 1.00-4.00 k = 0.0018φ3.3318 R² = 0.8687 81.72 19.8
6 0.40-1.00 k = 0.0017φ2.6893 R² = 0.6417 6.99 20.6
7 0.00-0.40 k = 4E-05φ3.1928 R² = 0.5529 0.22 12.9
Sample
Number
Core Ambient He Emp. Klink. Perm Grain
Depth Porosity at 400 psig Density RQI φz FZI Lithology(m) (% of Vb) (mD) (g/ml) HU
11 3198.83 11.9 23.8 2.91 0.44 0.136 3.264 coarse 5
16 3200.78 22.2 8.77 2.66 0.20 0.285 0.691 fine 6
HS1 3201.13 17.0 0.05 3.03 0.02 0.205 0.081 fine 7
18 3201.51 18.4 0.48 2.74 0.05 0.225 0.226 fine 7
DS1 3202.47 26.7 46.4 2.69 0.41 0.363 1.140 fine 5
HS2 3203.28 26.9 45.9 2.71 0.41 0.368 1.115 medium 5
22 3203.97 31.5 2022 2.68 2.51 0.461 5.456 medium 4
26 3205.30 21.7 36.1 2.79 0.40 0.277 1.461 medium 5
DS2 3205.55 29.3 2698 2.69 3.01 0.415 7.249 coarse 3
28 3206.03 24.0 114 2.70 0.68 0.315 2.170 coarse 5
32 3207.23 24.2 352 2.66 1.20 0.319 3.765 medium 5
DS3 3209.30 27.4 1245 2.68 2.12 0.378 5.594 medium 4
DS4 3212.82 24.7 1373 2.83 2.34 0.328 7.136 coarse 3
46 3213.58 12.6 0.28 2.67 0.05 0.145 0.323 fine 7
48 3214.28 30.0 216 2.67 0.84 0.429 1.961 fine 5
DS5 3215.37 23.7 2096 2.71 2.95 0.310 9.514 coarse 2
HS3 3215.86 27.4 9463 2.71 5.84 0.377 15.503 coarse 1
HS5 3226.10 23.0 1666 2.74 2.67 0.298 8.971 coarse 3
DS8 3227.81 7.4 0.04 2.88 0.02 0.080 0.296 lami 7
DS9 3228.31 31.6 4407 2.74 3.71 0.461 8.048 coarse 3
69 3229.32 27.7 733 2.66 1.62 0.382 4.227 coarse 4
72 3230.37 28.1 703 2.69 1.57 0.391 4.018 coarse 4
74 3231.02 22.1 26.5 2.68 0.34 0.284 1.212 medium 5
75 3232.30 27.0 455 2.69 1.29 0.369 3.494 coarse 5
DS10 3232.63 28.6 1196 2.69 2.03 0.400 5.078 medium 4
78 3234.29 28.4 1631 2.67 2.38 0.396 6.014 coarse 3
80 3235.10 26.6 3410 2.69 3.55 0.363 9.801 coarse 2
83 3235.68 27.2 9279 2.67 5.79 0.375 15.472 coarse 1
84 3236.38 27.8 6780 2.70 4.90 0.385 12.731 coarse 2
DS11 3236.99 27.8 3445 2.69 3.50 0.385 9.084 coarse 2
85 3237.55 22.7 58.2 2.65 0.50 0.293 1.715 fine 5
87 3238.40 15.9 0.50 3.25 0.06 0.188 0.296 clay 7
DS12 3239.24 23.4 17.8 2.66 0.27 0.306 0.893 6
7 Hydraulic Units were formed.
Most of the core samples taken from gas zoneare of HU 5. (avg. φ=19.8% , avg. k=81.72md)
Most of the core samples takes from oil zoneare of HU 3. (avg. φ=26% , avg. k=1900.73md)
Part A: Generation of Global J-function curve◦ Get capillary pressure data from core samples.
◦ Convert Pc to J-Function using the formula:
◦ Plot all “J(Sw) Vs. Sw” on the same graphs, andfind a representative curve for the family. This iscalled the Global Curve.
Sample No. DS 33 Sample No. 156 Sample No. 149
Porosity: 0.239 Porosity: 0.248 Porosity: 0.256
Permeability 2647.4 Permeability 1914.0 Permeability 1283.0
σ cos θ 26.0 σ cos θ 26.0 σ cos θ 26.0
Pc Sw J Pc Sw J Pc Sw J
[psi] [-] [-] [psi] [-] [-] [psi] [-] [-]
0.41 0.894 0.3570 0.40 0.380 0.2923 0.39 0.918 0.230199
1.02 0.278 0.8950 1.00 0.284 0.7328 0.98 0.918 0.577096
2.06 0.245 1.8073 2.02 0.259 1.4799 1.98 0.358 1.165383
4.99 0.222 4.3732 4.90 0.239 3.5809 4.78 0.307 2.819938
8.87 0.208 7.7746 8.70 0.223 6.3661 8.51 0.280 5.013224
13.08 0.195 11.4635 12.83 0.210 9.3868 12.54 0.264 7.391947
18.11 0.176 15.8664 17.76 0.191 12.9921 17.36 0.248 10.23107
Sample No. 91 Sample No. 140 Sample No. 32
Porosity: 0.258 Porosity: 0.213 Porosity: 0.239
Permeability 625.5 Permeability 350.0 Permeability 2647.4
σ cos θ 26.0 σ cos θ 26.0 σ cos θ 26.0
Pc Sw J Pc Sw J Pc Sw J
[psi] [-] [-] [psi] [-] [-] [psi] [-] [-]
0.40 0.752 0.1650 0 0.689 0 0 0.837 0
1.12 0.397 0.4585 0.56 0.212 0.1898 1.10 0.382 0.3502
1.89 0.329 0.7748 0.81 0.148 0.2733 1.59 0.314 0.5043
4.48 0.273 1.8338 1.10 0.135 0.3720 3.98 0.251 1.2641
10.07 0.224 4.1261 1.82 0.077 0.6149 12.00 0.173 3.8134
19.74 0.192 8.0872 3.80 0.073 1.2830 54.00 0.135 17.1587
47.28 0.147 19.3699 11.90 0.056 4.0160 99.47 0.098 31.6036
18.92 0.039 6.3846 148.30 0.083 47.1199
0.0
5.0
10.0
15.0
20.0
25.0
30.0
0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1
J (S
w)
Sw
J Vs Sw
J
DS 33
156
149
91
140
32
Part 2:Calculation of Free Water Level (FWL)◦ Take a number of samples, and calculate their
threshold/displacement pressure using empiricalformula:
◦ Convert Pt into Height
◦ The Pt of the most comparable sample to theGOC is considered.
◦ Depth of FWL = GOC + H
Plug Id K (mD) PHI (%)
Depth
(m) Pt h * (m)
72 703 28.1 3230.37 0.4398 0.7751
150 1628 24.0 3281.42 0.3065 0.5402
154 1561 26.1 3284.51 0.3121 0.5500
162 933 16.4 3290.96 0.3894 0.6863
37V 2085 25.4 3210.66 0.2756 0.4857
h*= height of WOC above free water level
OWC = 3291.7 mMDBRT
FWL = 3291.7 + 0.6862 = 3292.39
Part 3: Calculation of Water Saturation◦ For each sample, calculate Height above Free Water Level
(FWL)
◦ Convert Height above FWL into capillary pressure inreservoir condition
◦ Convert Pc at reservoir conditions to Pc at laboratoryconditions
◦ Change Pc (lab) to J(Sw)
◦ Calculate Sw by correlating from Global J-FunctionCurve.
Rho-oil = 0.247 σ . CosθRho-water = 0.42 Air/Gas-Hg Air/Gas-Brine Air/Gas-Oil Oil-Brine
rho gas = 0.129 [dynes/cm] [dynes/cm] [dynes/cm] [dynes/cm]Laboratory 368 72 24 42Reservoir 50 26
Sample
Number
Core Sw from Height PC (res) (tcosθ)lab Pc (lab) J Sw
Depth φ K Dean above H*Δρ*3.28 (tcosθ)res
(m) Stark FWL
11 3198.83 11.9 23.8 93.56 89.301 72/50 128.594 7.854 0.228
16 3200.78 22.2 8.77 91.61 87.440 1.44 125.913 3.425 0.268
HS1 3201.13 17.0 0.05 91.26 87.106 1.44 125.432 0.288 0.384
18 3201.51 18.4 0.48 90.88 86.743 1.44 124.910 0.876 0.332
DS1 3202.47 26.7 46.4 20.5 89.92 85.827 1.44 123.591 7.059 0.233
HS2 3203.28 26.9 45.9 89.11 85.054 1.44 122.477 6.924 0.234
22 3203.97 31.5 2022 88.42 84.395 1.44 121.529 42.117 0.149
26 3205.30 21.7 36.1 87.09 83.126 1.44 119.701 6.681 0.236
DS2 3205.55 29.3 2698 8.8 86.84 82.887 1.44 119.357 49.547 0.141
28 3206.03 24.0 114 86.36 82.429 1.44 118.698 11.195 0.212
32 3207.23 24.2 352 85.16 81.284 1.44 117.048 19.355 0.186
DS3 3209.30 27.4 1245 16.9 83.09 79.308 1.44 114.203 33.305 0.160
DS4 3212.82 24.7 1373 11.4 79.57 75.948 1.44 109.365 35.299 0.158
46 3213.58 12.6 0.28 78.81 75.223 1.44 108.320 0.698 0.343
48 3214.28 30.0 216 78.11 74.554 1.44 107.358 12.460 0.207
DS5 3215.37 23.7 2096 8.9 77.02 73.514 1.44 105.860 43.105 0.148
HS3 3215.86 27.4 9463 76.53 73.046 1.44 105.187 84.684 0.116
HS5 3226.10 23.0 1666 66.29 63.272 1.44 91.112 33.592 0.160
DS8 3227.81 7.4 0.04 75.2 64.58 61.636 1.44 88.756 0.289 0.384
DS9 3228.31 31.6 4407 12.3 64.08 61.163 1.44 88.075 45.056 0.146
69 3229.32 27.7 733 63.07 60.199 1.44 86.687 19.317 0.186
72 3230.37 28.1 703 62.02 59.197 1.44 85.243 18.460 0.188
74 3231.02 22.1 26.5 61.37 58.576 1.44 84.350 4.001 0.260
75 3232.30 27.0 455 60.09 57.355 1.44 82.591 14.691 0.199
DS10 3232.63 28.6 1196 11.6 59.76 57.040 1.44 82.137 23.003 0.178
3190
3210
3230
3250
3270
3290
0.00 0.10 0.20 0.30 0.40 0.50 0.60
Dep
th (m
MD
BR
T)
Sw
Sw From Pc
Sw
3190
3210
3230
3250
3270
3290
0 0.1 0.2 0.3 0.4 0.5 0.6
Dep
th (m
MD
TR
T)
Sw
Comparison of Saturation from Log and Pc
Sw (log)
Sw (J)
3200
3210
3220
3230
3240
3250
3260
3270
3280
3290
3300
0 10 20 30 40 50 60 70 80
Dep
th (m
MD
BR
T)
Sw %
Comparison of Saturation from Dean Stark and Pc
Sw (DS)
Sw (J)
The saturation profile does not show anypredictable behavior, because;◦ The reservoir is highly heterogeneous◦ The petrophysical properties show huge variation
The Sw values from Dean Stark are morecomparable to values from J-function thanlog.
The log values are initial readings withouttuning with electrical properties from SCAL.
Permeability is defined as the ability of amedium to allow a fluid flow. It is a measureof fluid conductivity of a material.
When two or more fluids flow in areservoir, they impede the flow of oneanother.
Relative permeability is the fluid conductivityof one fluid in the presence of anotherfluid(s).
Relative Permeability is expressed aspermeability on one fluid over the absolutepermeability.
There are two ways to get relativepermeability values:
1. Experimental Results Steady State Measurement
Unsteady State Measurement
2. Estimation from Capillary Pressure data
Drainage applies to processes where thewetting phase is reducing in concentration.
Imbibition applies to process where thewetting phase is increasing in concentration.
DRAINAGE IMBIBITION
Gas displacing oil(gas drive)
Water-flood Calculations(Water displaces oil and gas)
Gas replacing oil (gravity drainage)
Water Influx calculations(Water displaces Oil or gas)
Oil or gas displacing water
Procedure
1. Get Centrifuge Capillary Pressure Data.
2. Plot Pc Vs. Sw* and calculate the Pore Size Distribution Index, λ.
3. Put the value of λ in the equations of Krwand Krn.
4. Plot the relative permeability curves and average them.
Sample No. 91Swir 0.182Sor 0.226
Pc Sw Sw*[psi] [-] [-]0.40 0.752 0.9631.12 0.397 0.3621.89 0.329 0.2494.48 0.273 0.153
10.07 0.224 0.07019.74 0.192 0.017
λ = 1 Swi 0.182(2+3λ)/λ (2+λ)/λ Sor [-] : 0.226
4.78571 2.78571 1-Sor = Sm 0.774Sm - Swi 0.592
18.20 0.000 0.00000 0.85380 1.0000 1.0000 0.85380
20.00 0.030 5.49342E-08 0.85380 0.94011 0.9999 0.80262
30.00 0.199 0.00044 0.85380 0.64108 0.9888 0.54123
40.00 0.368 0.00839 0.85380 0.39912 0.9381 0.31969
50.00 0.537 0.05109 0.85380 0.21422 0.8229 0.15051
60.00 0.706 0.18909 0.85380 0.08639 0.6207 0.04578
70.00 0.875 0.52780 0.85380 0.01563 0.3106 0.00414
77.43 1.000 1.00217 0.85380 0.00000 -0.0013 0.00000
0.1
1
10
100
0.01 0.1 1
Pc
Sw*
Pc vs Sw*
Pc vs Sw*
Power (Pc vs Sw*)
Sample No. DS 33Swir 0.180Sor 0.098
Pc Sw Sw*[psi] [-] [-]
0.4 0.894 0.98827
1.0 0.278 0.13635
2.1 0.245 0.09015
5.0 0.222 0.05860
8.9 0.208 0.03831
13.1 0.195 0.02028
λ = 0.93 Swi 0.18(2+3λ)/λ (2+λ)/λ Sor [-] : 0.0985.15054 3.15054 1-Sor = Sm 0.902
Sm - Swi 0.722
18.00 0.000 0.0000 0.85655 1.00000 1.0000 0.85655
20.00 0.028 0.0000 0.85655 0.94537 9.9999 0.80974
30.00 0.166 0.0001 0.85655 0.69521 0.9965 0.59340
40.00 0.305 0.0022 0.85655 0.48343 0.9763 0.40428
50.00 0.443 0.0151 0.85655 0.31001 0.9230 0.24509
60.00 0.582 0.0614 0.85655 0.17496 0.8186 0.12267
70.00 0.720 0.1844 0.85655 0.07828 0.6444 0.04321
80.00 0.859 0.4564 0.85655 0.01996 0.3811 0.00652
90.00 0.997 0.9858 0.85655 0.00001 0.0087 0.00320
90.17 1.000 0.9976 0.85655 0.00000 0.0015 0.00000
0.1
1.0
10.0
100.0
0.01 0.1 1
Pc
Sw*
Pc Vs Sw*
Pc Vs Sw*
Power (Pc Vs Sw*)
Sample No. 127 VSwir 0.185Sor 0.171
Pc Sw Sw*[psi] [-] [-]
0.4 0.829 1.000
1.1 0.443 0.400
1.9 0.388 0.316
4.4 0.333 0.230
9.9 0.289 0.162
19.4 0.262 0.119
46.5 0.228 0.066
Swi 0.18λ = 1.22 Sor [-] : 0.098
(2+3λ)/λ (2+λ)/λ 1-Sor = Sm 0.9024.63934 2.63934 Sm - Swi 0.722
18.50 0.000 0.00000 0.84967 1.0000 1.0000 0.84967
20.00 0.023 0.00000 0.84967 0.9537 1.0000 0.81051
30.00 0.179 0.00034 0.84967 0.6747 0.9894 0.56723
40.00 0.334 0.00616 0.84967 0.4438 0.9447 0.35620
50.00 0.489 0.03624 0.84967 0.2610 0.8485 0.18817
60.00 0.644 0.13021 0.84967 0.1264 0.6864 0.07375
70.00 0.800 0.35450 0.84967 0.0401 0.4457 0.01519
80.00 0.955 0.80754 0.84967 0.0020 0.1145 0.00020
82.91 1.000 1.00051 0.84967 0.0000 0.0000 0.00000
0.1
1.0
10.0
100.0
0.01 0.1 1
Pc
Sw*
Pc Vs Sw*
Pc Vs Sw*
Power (Pc Vs Sw*)
0
0.2
0.4
0.6
0.8
1
0
0.2
0.4
0.6
0.8
1
0 0.2 0.4 0.6 0.8 1
Kr
Sw*
127 V
Krn
Krw
0
0.2
0.4
0.6
0.8
1
0
0.2
0.4
0.6
0.8
1
0 0.2 0.4 0.6 0.8 1
Kr
Sw*
DS 33
Krn
Krw
0
0.2
0.4
0.6
0.8
1
0
0.2
0.4
0.6
0.8
1
0 0.2 0.4 0.6 0.8 1
Kr
Sw*
91
Krn
Krw
0
0.2
0.4
0.6
0.8
1
0
0.2
0.4
0.6
0.8
1
0 0.2 0.4 0.6 0.8 1
Krw
Krn
Sw*
Relative Permeability
Krn
Krw
Basics of coring operations were covered.
Various experiments conducted were studied.
The reservoir was characterized based on flow behavior.
7 HU were formed.
Due to insufficient data, only ONE J-Function was defined, and using it the saturation distribution was obtained.
Relative permeability was also calculated using capillary pressure.
The when, why and how of coring and core analysis.
The planning and execution of a coring program.
The importance and applications of core analysis.
Thank You
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