Difference between revisions of "Pore-fluid interaction"

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==See also==
 
==See also==
* [[Hydrocarbon expulsion, [[migration]], and accumulation]]
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* [[Hydrocarbon expulsion, migration, and accumulation]]
 
* [[Characterizing rock quality]]
 
* [[Characterizing rock quality]]
* [[P<sub>c</sub> curves and saturation profiles]]
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* [[Pc curves and saturation profiles]]
* [[Converting p<sub>c</sub> curves to buoyancy, height, and pore throat radius]]
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* [[Converting Pc curves to buoyancy, height, and pore throat radius]]
 
* [[What is permeability?]]
 
* [[What is permeability?]]
 
* [[Relative permeability and pore type]]
 
* [[Relative permeability and pore type]]

Revision as of 20:30, 31 January 2014

Exploring for Oil and Gas Traps
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

Pore–fluid interaction determines the amount and rate of hydrocarbon recovery. Reservoir pore throat radius, buoyancy pressure, and fluid properties are the main elements controlling pore–fluid interaction. Since direct observation of pore–fluid interaction in the reservoir is impossible at present, capillary pressure and relative permeability analysis of rocks yields the most insight into the behavior of fluids in a particular pore system.

This section discusses pore–fluid interaction and techniques for predicting the behavior of fluid within a pore system.

See also

External links

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Pore-fluid interaction
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