Anisotropy and spatial variation of relative permeability and lithologic character of Tensleep Sandstone reservoirs in the Bighorn and Wind River basins, Wyoming. Quarterly report, January 1, 1996--March 31, 1996 Page: 3 of 6
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permeability algorithms, while relative permeability of the remaining 46 thin sections
will be defined only through the use of the relative permeability algorithms. These
samples will be used to further define trends in relative permeability in the Tensleep
An algorithm has been developed for predicting oil relative permeability curves
from distinct and measurable pore-network variables. From saturation data predicted
using this initial algorithm, another algorithm has been developed that accurately
predicts the relative permeability curve of water. These algorithms can be applied to
quickly and cheaply predict the relative permeability curves of both water and oil from
data derived from the pore structure. The calculated data can then be placed in a
sedimentologic and geometric framework to better understand how relative permeability
varies with respect to sedimentologic features. The algorithm for the oil relative
permeability curve is based on the work of Mowers2, Ehrlich3, and Ruzyla4. Portions of
these previous studies can be combined into a single equation that is based on the
Carman-Kozeny equation. This equation can then be modified and used for the prediction
of relative permeability. The equation used for the prediction of water relative
permeability is based on work by Honarpour et al.5 and Honarpours, and is an empirically
derived equation that uses predicted water saturations to determine the relative
permeability of water for that sample. Figure 1 shows an example of preliminarily
results from these equations. More testing of these algorithms must be completed, but
results to date clearly show that it is possible to predict relative permeability from
quantitative analysis of the pore structure using petrographic image analysis techniques.
The developed algorithms will now be further tested using the defined image
analysis techniques. Any revisions to these original equations will be made as shown to
be needed by more tests. The final developed algorithms will then be used to predict
both water and oil relative permeability curves for the remaining samples. The results
can then be placed into a geologic context, and the role of each sedimentologic feature in
regard to relative permeability anisotropy can be evaluated.
CO2 Flood -- Formation Alteration and Wellbore Damage
The work of this task is to establish criteria for the susceptibility of Tensleep
reservoirs to formation alteration resulting in a change in absolute or relative
permeability and possible wellbore scale damage during CO2 enhanced oil recovery. This
advanced reservoir characterization technology will be used to optimize recovery
efficiency. This task includes:
1. flow experiments on core material to examine the effects of CO2 flooding on
the alteration of the fluid and rock system;
2. examination of regional trends in water chemistry;
3. examination of local water chemistry trends at field scale; and
4. chemical modeling of both the reservoir and experimental systems in order to
scale-up the experiments to reservoir conditions.
During this quarter, chemical analyses of sample solutions of the fourth C02 core
flooding experiment, which was run in December 1995, have been completed. Results
showed that much anhydrite cement dissolved into solution at the early stage of the run,
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Dunn, T.L. Anisotropy and spatial variation of relative permeability and lithologic character of Tensleep Sandstone reservoirs in the Bighorn and Wind River basins, Wyoming. Quarterly report, January 1, 1996--March 31, 1996, report, April 26, 1996; United States. (digital.library.unt.edu/ark:/67531/metadc672505/m1/3/: accessed November 14, 2018), University of North Texas Libraries, Digital Library, digital.library.unt.edu; crediting UNT Libraries Government Documents Department.