Changes

[[file:predicting-reservoir-system-quality-and-performance_fig9-89.png|thumb|{{figure number|1}}From Hartmann and Coalson.<ref name=Hartmannandcoalson_1990>Hartmann, D. J., and E. B. Coalson, 1990, Evaluation of the Morrow sandstone in Sorrento field, Cheyenne County, Colorado, ''in'' S. A. Sonnenberg, L. T. Shannon, K. Rader, W. F. von Drehle, and G.W. Martin, eds., Morrow Sandstones of Southeast Colorado and Adjacent Areas: RMAG Symposium, p. 91-100.</ref> Courtesy Rocky Mountain Association of Geologists.]]

[[file:predicting-reservoir-system-quality-and-performance_fig9-89.png|thumb|{{figure number|1}}From Hartmann and Coalson.<ref name=Hartmannandcoalson_1990>Hartmann, D. J., and E. B. Coalson, 1990, Evaluation of the Morrow sandstone in Sorrento field, Cheyenne County, Colorado, ''in'' S. A. Sonnenberg, L. T. Shannon, K. Rader, W. F. von Drehle, and G.W. Martin, eds., Morrow Sandstones of Southeast Colorado and Adjacent Areas: RMAG Symposium, p. 91-100.</ref> Courtesy Rocky Mountain Association of Geologists.]]

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: Rocky Mountain Association of Geologists 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: Rocky Mountain Association of Geologists 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 (see [[Constructing a Pickett plot]]). 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: Rocky Mountain Association of Geologists 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: Rocky Mountain Association of Geologists Symposium, p. 149–158.</ref> or pyrite (Kristinick, personal communication). Formation factors measured on core samples from well 1 support this interpretation.

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.

 

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 [[:file:predicting-reservoir-system-quality-and-performance_fig9-88.png|Figure 2]].

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

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