Plausibility of Hydrocarbon Potential Analytics of Archie’s Model by Cementation Factor Pliability in Shaly Sand Reservoir

Anthony John Ilozobhie, Daniel Ikechukwu Egu


Comprehensive comparative analyses of 18 shaly sandstone zones in four wells of an Oil Field in the Niger Delta were carried using only the Archie Model with the appropriate cementation factor from a range of 1.3 to 2.0 This was done to comprehensively analyze and statistically validate the need for the applicability of m = 1.3. Detailed statistical analysis of water saturation results of lower and upper 95% confidence intervals for the standard deviations gave the least range of 0.00415 to 0.00724 (m=1.3), 0.00660 to 0.1151 (m=1.65) and maximum of 0.00996 to 0.01747 (m=2.0). This was however validated by the bias results of the standard deviation with -0.00025 for m=1.3, -0.00040 for m=1.65 and -0.00060 for m=2. Hydrocarbon saturation results of lower and upper 95% confidence intervals for the standard also gave the least values of 0.00427 to 0.00740 (m=1.3), 0.00680 to 0.01171 (m=1.65) and 0.01031 to 0.01773 (m=2.0). The bias results of the standard deviation gave the least for m=1.3 as -0.0002, -0.00032 for m=1.65 and -0.00048 for m=2.0. Hydrocarbon movability index results of lower and upper 95% confidence intervals for standard deviation gave the least range for m=1.3 of 0.00521 to 0.00934, 0.00793 to 0.01415 for m=1.65 and 0.01155 to 0.02049 for m=2.0. The bias results of the standard deviation gave also the least for m=1.3 as -0.00031, -0.00047 for m=1.65 and -0.00068 for m=2. The study reveals that the Archie Model predictions was improved with cementation factor of 1.3 and has favourable petrophysical parameters indicating higher hydrocarbon potential than the Simandoux  and when m=1.65 and 2.0. This model is a valuable tool in a shaly sand environment after thorough validation using the pickett plot.


Archie Models, cementation factor, porosity, hydrocarbon, water saturations

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