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  | isbn    = 0891816607

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''Porosity'' determines reservoir storage capacity. It is defined as the ratio of void space, commonly called pore volume, to bulk volume and is reported either as a fraction or a percentage. Almost all hydrocarbon reservoirs are composed of sedimentary rocks in which porosity values generally vary from 10 to 40% in sandstones and from 5 to 25% in carbonates.<ref name=pt05r36>Coneybeare, C. E. B., 1967, Influence of compaction on stratigraphic analysis: Canadian Petroleum Geology Bulletin, v. 15, p. 331–345.</ref><ref name=pt05r92>Keelan, D. K., 1982, Core analysis for aid in reservoir description: Journal of Petroleum Technology, v. 34, p. 2483–2491, DOI: [https://www.onepetro.org/journal-paper/SPE-10011-PA 10.2118/10011-PA].</ref>

''Porosity'' determines reservoir storage capacity. It is defined as the ratio of void space, commonly called pore volume, to bulk volume and is reported either as a fraction or a percentage. Almost all hydrocarbon reservoirs are composed of sedimentary rocks in which porosity values generally vary from 10 to 40% in sandstones and from 5 to 25% in carbonates.<ref name=pt05r36>Coneybeare, C. E. B., 1967, Influence of compaction on stratigraphic analysis: Canadian Petroleum Geology Bulletin, v. 15, p. 331–345.</ref><ref name=pt05r92>Keelan, D. K., 1982, Core analysis for aid in reservoir description: Journal of Petroleum Technology, v. 34, p. 2483–2491, DOI: [https://www.onepetro.org/journal-paper/SPE-10011-PA 10.2118/10011-PA].</ref> (Also see [[Reservoir quality]].)

==Definition of porosity terms==

==Definition of porosity terms==