Factors influencing porosity and permeability, Wilcox Group (Eocene), Karnes County, Texas
type: CreativeWork
description: Petrographic and petrophysical data from 57 sandstone samples collected from the available parts of a 2500 ft section of core (-5094 ft to -7474 ft) recovered from the Seaboard Oil Kolodziejcyk #1 well in southeastern Karnes County were used to determine the diagenetic changes within the rocks and their effect on porosity and, indirectly, permeability. The core penetrated deposits of shoreface (with probable tidal channel and/or small (tidal?) delta), tidal flat and bay-lagoon environments. Framework grain mineralogy is similar for samples regardless of environment of deposition. The sandstones are chiefly fine to very fine and well sorted with an average composition of Q₅₉ F₁₆ R₂₅; matrix values range from 0 to 46 percent and cement values range from 8 to 34 percent. Permeability values range from nil to over 650 millidarcies. Porosity values, also determined by gas injection, range from 6 to 36 percent and thin section determined porosity values range from 0 to 20 percent. Petrophysically-determined porosity has a positive correlation with both "petrophysical" and "petrographic" porosity. Initial porosity of sand was reduced by the following sequence of partly overlapping events: bioturbation penecontemporaneous with deposition; compactional rotation of framework grains; compactional deformation of ductile grains; and precipitation of authigenic quartz, kaolinite, calcite, ferroan calcite and dolomite cement. A few samples lost most porosity due to bioturbation penecontemporaneous with deposition but the majority lost about 12 percent due to compactional effects followed by up to 30 percent loss by cementation. Up to 21 percent porosity resulted from the dissolution of calcite from sandstone by natural acid formation water at about the maximum depth of burial. This secondary porosity formed by the dissolution of both calcite cement and calcite-replaced framework grains (chiefly plagioclase) and is most pronounced in shoreface and tidal channel sandstones. Secondar…
abstract: Petrographic and petrophysical data from 57 sandstone samples collected from the available parts of a 2500 ft section of core (-5094 ft to -7474 ft) recovered from the Seaboard Oil Kolodziejcyk #1 well in southeastern Karnes County were used to determine the diagenetic changes within the rocks and their effect on porosity and, indirectly, permeability. The core penetrated deposits of shoreface (with probable tidal channel and/or small (tidal?) delta), tidal flat and bay-lagoon environments. Framework grain mineralogy is similar for samples regardless of environment of deposition. The sandstones are chiefly fine to very fine and well sorted with an average composition of Q₅₉ F₁₆ R₂₅; matrix values range from 0 to 46 percent and cement values range from 8 to 34 percent. Permeability values range from nil to over 650 millidarcies. Porosity values, also determined by gas injection, range from 6 to 36 percent and thin section determined porosity values range from 0 to 20 percent. Petrophysically-determined porosity has a positive correlation with both "petrophysical" and "petrographic" porosity. Initial porosity of sand was reduced by the following sequence of partly overlapping events: bioturbation penecontemporaneous with deposition; compactional rotation of framework grains; compactional deformation of ductile grains; and precipitation of authigenic quartz, kaolinite, calcite, ferroan calcite and dolomite cement. A few samples lost most porosity due to bioturbation penecontemporaneous with deposition but the majority lost about 12 percent due to compactional effects followed by up to 30 percent loss by cementation. Up to 21 percent porosity resulted from the dissolution of calcite from sandstone by natural acid formation water at about the maximum depth of burial. This secondary porosity formed by the dissolution of both calcite cement and calcite-replaced framework grains (chiefly plagioclase) and is most pronounced in shoreface and tidal channel sandstones. Secondar…
author: Stanton, George Duwe, 1949-
language: en
keywords: Karnes County sandstone, Wilcox Group sandstone, Texas sandstone, Texas sandstone porosity, Texas sandstone permeability, Texas sandstone diagenesis, Sandstone porosity factors, Sandstone permeability factors, Wilcox sandstones
date published: 1977
date modified: 2026-07-24T05:01:10Z
provider: University of Texas
publisher: Networked Digital Library of Theses and Dissertations
type: WebPage
source organization: University of Texas at Austin

PropertyValue
property ID: Handle
value: https://hdl.handle.net/2152/125696

PropertyValue
property ID: DOI
value: 10.26153/tsw/52256