Changes

==Pickett plot==

==Pickett plot==

Formation-water resistivities and water saturations were estimated from Pickett plots. The inferred cementation exponent ''(m)'' is 1.8 because of the presence of clays, well-connected solution pores (e.g., <ref name=ch09r31>James, S., W., 1989, Diagenetic history and reservoir characteristics of a deep Minnelusa reservoir, Hawk Point field, Powder River basin, Wyoming, in Coalson, E., B., Kaplan, S., S., Keighin, C., W., Oglesby, C., A., Robinson, J., W., eds., Petrogenesis and Petrophysics of Selected Sandstone Reservoirs of the Rocky Mountain Region: RMAG Symposium, p. 81–96.</ref><ref name=ch09r39>Muller, M., M., Coalson, E., B., 1989, Diagenetic and petrophysical variations of the Dakota sandstone, Henry field, Green River basin, Wyoming, in Coalson, E., B., Kaplan, S., S., Keighin, C., W., Oglesby, C., A., Robinson, J., W., eds., Petrogenesis and Petrophysics of Selected Sandstone Reservoirs of the Rocky Mountain Region: RMAG Symposium, p. 149–158.</ref> or pyrite (Kristinick, personal communication). Formation factors measured on core samples from well 1 support this interpretation.

Formation-water resistivities and water saturations were estimated from Pickett plots. The inferred cementation exponent ''(m)'' is 1.8 because of the presence of clays, well-connected solution pores (e.g., <ref name=ch09r31>James, S., W., 1989, Diagenetic history and reservoir characteristics of a deep Minnelusa reservoir, Hawk Point field, Powder River basin, Wyoming, in Coalson, E., B., Kaplan, S., S., Keighin, C., W., Oglesby, C., A., Robinson, J., W., eds., Petrogenesis and Petrophysics of Selected Sandstone Reservoirs of the Rocky Mountain Region: RMAG Symposium, p. 81–96.</ref><ref name=ch09r39>Muller, M., M., Coalson, E., B., 1989, Diagenetic and petrophysical variations of the Dakota sandstone, Henry field, Green River basin, Wyoming, in Coalson, E., B., Kaplan, S., S., Keighin, C., W., Oglesby, C., A., Robinson, J., W., eds., Petrogenesis and Petrophysics of Selected Sandstone Reservoirs of the Rocky Mountain Region: RMAG Symposium, p. 149–158.</ref> or pyrite (Kristinick, personal communication). Formation factors measured on core samples from well 1 support this interpretation.

The Pickett below shows data from well 11. The number labels represent the flow units from Figure 9-88.

The Pickett plot in [[:file:predicting-reservoir-system-quality-and-performance_fig9-89.png|Figure 1]] shows data from well 11. The number labels represent the flow units from Figure 9-88.

 

[[file:predicting-reservoir-system-quality-and-performance_fig9-89.png|thumb|{{figure number|9-89}}. Copyright: Hartmann and Coalson, 1990; courtesy RMAG.]]

==Saturation exponents, ''n''==

==Saturation exponents, ''n''==