Simulation study of surfactant transport mechanisms in naturally fractured reservoirs

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dc.contributor.advisor Pope , Gary A .
dc.contributor.committeeMember Mohanty , Kishore K .
dc.creator Abbasi Asl , Yousef 2011 -01 -03T18 :42 :26Z 2011 -01 -03T18 :42 :33Z 2014 -02 -19T22 :48 :30Z 2011 -01 -03T18 :42 :26Z 2011 -01 -03T18 :42 :33Z 2014 -02 -19T22 :48 :30Z 2010 -08 2011 -01 -03 August 2010
dc.identifier.uri http : / /hdl .handle .net /2152 /ETD -UT -2010 -08 -1707
dc.description.abstract Surfactants both change the wettability and lower the interfacial tension by various degrees depending on the type of surfactant and how it interacts with the specific oil . Ultra low IFT means almost zero capillary pressure , which in turn indicates little oil should be produced from capillary imbibition when the surfactant reduces the IFT in naturally fractured oil reservoirs that are mixed -wet or oil -wet . What is the transport mechanism for the surfactant to get far into the matrix and how does it scale ? Molecular diffusion and capillary pressure are much too slow to explain the experimental data . Recent dynamic laboratory data suggest that the process is faster when a pressure gradient is applied compared to static tests . A mechanistic chemical compositional simulator was used to study the effect of pressure gradient on chemical oil recovery from naturally fractured oil reservoirs for several different chemical processes (polymer , surfactant , surfactant -polymer , alkali -surfactant -polymer flooding ) . The fractures were simulated explicitly by using small gridblocks with fracture properties . Both homogeneous and heterogeneous matrix blocks were simulated . Microemulsion phase behavior and related chemistry and physics were modeled in a manner similar to single porosity reservoirs . The simulations indicate that even very small pressure gradients (transverse to the flow in the fractures ) are highly significant in terms of the chemical transport into the matrix and that increasing the injected fluid viscosity greatly improves the oil recovery . Field scale simulations show that the transverse pressure gradients promote transport of the surfactant into the matrix at a feasible rate even when there is a high contrast between the permeability of the fractures and the matrix . These simulations indicate that injecting a chemical solution that is viscous (because of polymer or foam or microemulsion ) and lowers the IFT as well as alters the wettability from mixed -wet to water -wet , produces more oil and produces it faster than static chemical processes . These findings have significant implications for enhanced oil recovery from naturally fractured oil reservoirs and how these processes should be optimized and scaled up from the laboratory to the field .
dc.format.mimetype application /pdf
dc.language.iso eng
dc.subject Wettability
dc.subject IFT
dc.subject Simulation
dc.subject Imbibition
dc.subject Fractured
dc.subject Oil -wet
dc.subject Mixed -wet
dc.subject Water -wet
dc.subject Interfacial tension
dc.subject UTCHEM
dc.subject Capillary
dc.subject Gravity
dc.subject Microemulsion
dc.subject Surfactant
dc.subject Alkali
dc.subject Polymer
dc.subject Recovery
dc.title Simulation study of surfactant transport mechanisms in naturally fractured reservoirs
dc.description.department Petroleum and Geosystems Engineering
dc.type.genre thesis *
dc.type.material text * Master of Science in Engineering Masters Petroleum Engineering University of Texas at Austin Petroleum and Geosystems Engineering 2011 -01 -03T18 :42 :33Z


Simulation study of surfactant transport mechanisms in naturally fractured reservoirs. Master's thesis, University of Texas at Austin. Available electronically from http : / /hdl .handle .net /2152 /ETD -UT -2010 -08 -1707 .

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