Difference between revisions of "Sorrento water saturation calculations"
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[[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 | + | [[file:predicting-reservoir-system-quality-and-performance_fig9-88.png|thumb|{{figure number|2}}From Hartmann and Coalson.<ref name=Hartmannandcoalson_1990 /> Courtesy Rocky Mountain Association of Geologists.]] |
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| + | 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''== | ||
Revision as of 19:57, 12 March 2014
| Exploring for Oil and Gas Traps | |
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| Series | Treatise in Petroleum Geology |
|---|---|
| Part | Predicting the occurrence of oil and gas traps |
| Chapter | Predicting reservoir system quality and performance |
| Author | Dan J. Hartmann, Edward A. Beaumont |
| Link | Web page |
| Store | AAPG Store |
Method
Density logs were the primary source of porosity values. Matrix density appears to be about 2.68 g/cc, based on core-measured grain densities (consistent with the presumed mineralogy of the sandstones). Crosspiot porosities were not used to avoid introducing a systematic error in these variably shaly sandstones.[1]
Pickett plot
Figure 1 From Hartmann and Coalson.[2] Courtesy Rocky Mountain Association of Geologists.
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., [3][4] or pyrite (Kristinick, personal communication). Formation factors measured on core samples from well 1 support this interpretation.
Figure 2 From Hartmann and Coalson.[2] Courtesy Rocky Mountain Association of Geologists.
The Pickett plot in Figure 1 shows data from well 11. The number labels represent the flow units from Figure 2.
Saturation exponents, n
Saturation exponents in) measured on samples from well 1 showed variations that relate to pore geometry. Microporous siltstones displayed n greater than 2, indicating either very tortuous pore systems or incomplete saturation by brine during testing. Saturation exponents were less than 2 in the best porosity type. This implies the reservoir is somewhat shaly. However, n was assumed equal to 2 for log calculations because the lab data were not far from that value and because lab measurements of saturation exponents are notoriously difficult.
See also
- Evaluation of saturation profiles
- Setting and structure of the Sorrento field
- Morrow lithofacies and pore types
- Petrophysical analysis of Sorrento field wells
- Water saturation profile for Sorrento field
References
- ↑ Patchett, J., G., Coalson, E., B., 1982, The determination of porosity in sandstone and shaly sandstone, part 2: effects of complex mineralogy and hydrocarbons: 23rd Annual SPWLA Logging Symposium, July 6–9, paper T, 50 p.
- ↑ 2.0 2.1 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.
- ↑ 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.
- ↑ 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.
External links
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