Porosity

ADVERTISEMENT
From SEG Wiki
Jump to: navigation, search
Other languages:
English • ‎español
Digital Imaging and Deconvolution: The ABCs of Seismic Exploration and Processing
DigitalImaging.png
Series Geophysical References Series
Title Digital Imaging and Deconvolution: The ABCs of Seismic Exploration and Processing
Author Enders A. Robinson and Sven Treitel
Chapter 3
DOI http://dx.doi.org/10.1190/1.9781560801610
ISBN 9781560801481
Store SEG Online Store

Porous and permeable rocks are required for an oil reservoir to form. Porosity is defined as pore volume per unit gross volume of rock. Effective porosity is the porosity that is available to free fluids, excluding unconnected porosity]] and space occupied by bound water and disseminated shale. A porous rock consists of a solid skeleton and a continuously connected fluid phase.

There are various types of porositiy. Intergranular porosity is common in sandstone. Rocks with vugular porosity contain small cavities and connected channels created by solution and recrystallization in existing rock. Fracture porosity consists of intersecting cracks caused by tectonic stresses applied to an otherwise impermeable rock.

What are primary porosity and secondary porosity? Primary porosity is the porosity that remains after sediments have been compacted but have not been changed by subsequent chemical action or water flow through them. Secondary porosity is the additional porosity created by subsequent changes in sediments — especially such changes as fissures, fractures, solution vugs, and porosity resulting from dolomitization. Many rocks have small amounts of pore space in the form of isolated microcracks. It is useful to look at this as a characteristic of the skeleton and to reserve the term porosity for interconnected space capable of supporting fluid flow.

How is porosity determined? Porosity is determined from cores, from sonic logs, from density logs, from neutron logs, or from resistivity logs. In the study of seismic-wave propagation through rocks, it is not possible to specify each grain, vug, or crack. A means of determining average properties is necessary. Two significant approaches are Gassmann’s theory and Biot’s theory (Gassmann, 1951[1]; Biot, 1956[2]).


References

[3]
[4]
[5]

Continue reading

Previous section Next section
Seismic interpretation Absorption loss and transmission loss
Previous chapter Next chapter
Digital Imaging Sampling

Table of Contents (book)


Also in this chapter


External links

find literature about
Porosity
SEG button search.png Datapages button.png GeoScienceWorld button.png OnePetro button.png Schlumberger button.png Google button.png AGI button.png
  1. Gassmann, F., 1951, Ueber die elastizitaet poroeser medien: Vierteljahresschrift der Naturforschenden Gesellschaft in Zuerich, 96, 1–23.
  2. Biot, M. A., 1956, The theory of propagation of elastic waves in a fluid-saturated porous solid, Parts I and II: Journal of the Acoustical Society of America, 28, 168–191.
  3. Whaley, J., 2017, Oil in the Heart of South America, https://www.geoexpro.com/articles/2017/10/oil-in-the-heart-of-south-america], accessed November 15, 2021.
  4. Wiens, F., 1995, Phanerozoic Tectonics and Sedimentation of The Chaco Basin, Paraguay. Its Hydrocarbon Potential: Geoconsultores, 2-27, accessed November 15, 2021; https://www.researchgate.net/publication/281348744_Phanerozoic_tectonics_and_sedimentation_in_the_Chaco_Basin_of_Paraguay_with_comments_on_hydrocarbon_potential
  5. Alfredo, Carlos, and Clebsch Kuhn. “The Geological Evolution of the Paraguayan Chaco.” TTU DSpace Home. Texas Tech University, August 1, 1991. https://ttu-ir.tdl.org/handle/2346/9214?show=full.