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You searched for +publisher:"University of Texas – Austin" +contributor:("DiCarlo, David"). Showing records 1 – 27 of 27 total matches.

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University of Texas – Austin

1. -8867-8438. Improved permeability estimation of formation damage through imaged core flooding experiments.

Degree: MSin Engineering, Petroleum Engineering, 2016, University of Texas – Austin

 The infiltration of fines into a reservoir during drilling or water reinjection and the accompanying production decline or loss of injectivity, are long-standing problems in… (more)

Subjects/Keywords: Filtration; CT scan; Bi-disperse particle; Glass bead

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APA (6th Edition):

-8867-8438. (2016). Improved permeability estimation of formation damage through imaged core flooding experiments. (Masters Thesis). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/47001

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Chicago Manual of Style (16th Edition):

-8867-8438. “Improved permeability estimation of formation damage through imaged core flooding experiments.” 2016. Masters Thesis, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/47001.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

MLA Handbook (7th Edition):

-8867-8438. “Improved permeability estimation of formation damage through imaged core flooding experiments.” 2016. Web. 06 Dec 2019.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Vancouver:

-8867-8438. Improved permeability estimation of formation damage through imaged core flooding experiments. [Internet] [Masters thesis]. University of Texas – Austin; 2016. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/47001.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Council of Science Editors:

-8867-8438. Improved permeability estimation of formation damage through imaged core flooding experiments. [Masters Thesis]. University of Texas – Austin; 2016. Available from: http://hdl.handle.net/2152/47001

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete


University of Texas – Austin

2. Xin, Yichen. Experiment design and improvement for PGE 427 properties of petroleum fluids.

Degree: MSin Engineering, Petroleum Engineering, 2018, University of Texas – Austin

 PGE 427 Properties of Petroleum Fluids is an undergraduate core course focused on the physical properties of organic chemicals (a.k.a. Fluids). However the corresponding lab… (more)

Subjects/Keywords: Undergraduate lab; Properties of fluids

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APA (6th Edition):

Xin, Y. (2018). Experiment design and improvement for PGE 427 properties of petroleum fluids. (Masters Thesis). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/63775

Chicago Manual of Style (16th Edition):

Xin, Yichen. “Experiment design and improvement for PGE 427 properties of petroleum fluids.” 2018. Masters Thesis, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/63775.

MLA Handbook (7th Edition):

Xin, Yichen. “Experiment design and improvement for PGE 427 properties of petroleum fluids.” 2018. Web. 06 Dec 2019.

Vancouver:

Xin Y. Experiment design and improvement for PGE 427 properties of petroleum fluids. [Internet] [Masters thesis]. University of Texas – Austin; 2018. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/63775.

Council of Science Editors:

Xin Y. Experiment design and improvement for PGE 427 properties of petroleum fluids. [Masters Thesis]. University of Texas – Austin; 2018. Available from: http://hdl.handle.net/2152/63775


University of Texas – Austin

3. Senthilnathan, Siddharth. Surface-coated silica nanoparticles for conformance control of buoyancy-driven CO₂ flow: Surface-coated silica nanoparticles for conformance control of buoyancy-driven CO2 flow.

Degree: MSin Engineering, Petroleum Engineering, 2017, University of Texas – Austin

 In light of growing concerns over rising atmospheric concentrations of greenhouse gases like carbon dioxide (CO₂), carbon capture and storage (CCS) has been suggested as… (more)

Subjects/Keywords: Buoyancy; CO2; Carbon dioxide; Sequestration; Climate change; Nanoparticles; Coreflood; Conformance control; Sweep efficiency; Reservoir engineering; CO₂

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APA (6th Edition):

Senthilnathan, S. (2017). Surface-coated silica nanoparticles for conformance control of buoyancy-driven CO₂ flow: Surface-coated silica nanoparticles for conformance control of buoyancy-driven CO2 flow. (Masters Thesis). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/64206

Chicago Manual of Style (16th Edition):

Senthilnathan, Siddharth. “Surface-coated silica nanoparticles for conformance control of buoyancy-driven CO₂ flow: Surface-coated silica nanoparticles for conformance control of buoyancy-driven CO2 flow.” 2017. Masters Thesis, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/64206.

MLA Handbook (7th Edition):

Senthilnathan, Siddharth. “Surface-coated silica nanoparticles for conformance control of buoyancy-driven CO₂ flow: Surface-coated silica nanoparticles for conformance control of buoyancy-driven CO2 flow.” 2017. Web. 06 Dec 2019.

Vancouver:

Senthilnathan S. Surface-coated silica nanoparticles for conformance control of buoyancy-driven CO₂ flow: Surface-coated silica nanoparticles for conformance control of buoyancy-driven CO2 flow. [Internet] [Masters thesis]. University of Texas – Austin; 2017. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/64206.

Council of Science Editors:

Senthilnathan S. Surface-coated silica nanoparticles for conformance control of buoyancy-driven CO₂ flow: Surface-coated silica nanoparticles for conformance control of buoyancy-driven CO2 flow. [Masters Thesis]. University of Texas – Austin; 2017. Available from: http://hdl.handle.net/2152/64206


University of Texas – Austin

4. -0657-6329. Experimental studies on the reservoir dynamics of water-based and gas-based fracturing fluids in tight rocks.

Degree: MSin Engineering, Petroleum Engineering, 2017, University of Texas – Austin

 Low permeability formations, including shale and tight reservoirs, have contributed over 50% of U.S. annual oil production. Many of these formations are oil productive formations,… (more)

Subjects/Keywords: Fracturing fluid; Reservoir dynamics; Water block; Gas block; Tight reservoir; Unconventional reservoir

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APA (6th Edition):

-0657-6329. (2017). Experimental studies on the reservoir dynamics of water-based and gas-based fracturing fluids in tight rocks. (Masters Thesis). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/62766

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Chicago Manual of Style (16th Edition):

-0657-6329. “Experimental studies on the reservoir dynamics of water-based and gas-based fracturing fluids in tight rocks.” 2017. Masters Thesis, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/62766.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

MLA Handbook (7th Edition):

-0657-6329. “Experimental studies on the reservoir dynamics of water-based and gas-based fracturing fluids in tight rocks.” 2017. Web. 06 Dec 2019.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Vancouver:

-0657-6329. Experimental studies on the reservoir dynamics of water-based and gas-based fracturing fluids in tight rocks. [Internet] [Masters thesis]. University of Texas – Austin; 2017. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/62766.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Council of Science Editors:

-0657-6329. Experimental studies on the reservoir dynamics of water-based and gas-based fracturing fluids in tight rocks. [Masters Thesis]. University of Texas – Austin; 2017. Available from: http://hdl.handle.net/2152/62766

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete


University of Texas – Austin

5. Alramadan, Hamdi Ahmed. Experimental evaluation of surface treated nanoparticles and their effect on wettability alteration of carbonate surfaces and oil-brine interfacial tension.

Degree: MSin Engineering, Petroleum engineering, 2016, University of Texas – Austin

 The alteration of rock surface wettability and the reduction of oil/brine interfacial tension enhances oil recovery from the reservoir. Most of the carbonate rock reservoirs… (more)

Subjects/Keywords: Nanoparticles; Wettability; IFT; Interfacial tension; Carbonates

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APA (6th Edition):

Alramadan, H. A. (2016). Experimental evaluation of surface treated nanoparticles and their effect on wettability alteration of carbonate surfaces and oil-brine interfacial tension. (Masters Thesis). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/41708

Chicago Manual of Style (16th Edition):

Alramadan, Hamdi Ahmed. “Experimental evaluation of surface treated nanoparticles and their effect on wettability alteration of carbonate surfaces and oil-brine interfacial tension.” 2016. Masters Thesis, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/41708.

MLA Handbook (7th Edition):

Alramadan, Hamdi Ahmed. “Experimental evaluation of surface treated nanoparticles and their effect on wettability alteration of carbonate surfaces and oil-brine interfacial tension.” 2016. Web. 06 Dec 2019.

Vancouver:

Alramadan HA. Experimental evaluation of surface treated nanoparticles and their effect on wettability alteration of carbonate surfaces and oil-brine interfacial tension. [Internet] [Masters thesis]. University of Texas – Austin; 2016. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/41708.

Council of Science Editors:

Alramadan HA. Experimental evaluation of surface treated nanoparticles and their effect on wettability alteration of carbonate surfaces and oil-brine interfacial tension. [Masters Thesis]. University of Texas – Austin; 2016. Available from: http://hdl.handle.net/2152/41708


University of Texas – Austin

6. Singhal, Vivek, Ph. D. Design and development of an X-ray sensor to measure the density and flow rate of drilling fluids in high pressure lines.

Degree: PhD, Mechanical Engineering, 2019, University of Texas – Austin

 There is a need for advanced technology that can accurately measure the density and mass flow rate of drilling fluids at the high pressure well… (more)

Subjects/Keywords: Density; Flow rate; High pressure; X-ray; Drilling; Automation; Sensor; Measurement

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APA (6th Edition):

Singhal, Vivek, P. D. (2019). Design and development of an X-ray sensor to measure the density and flow rate of drilling fluids in high pressure lines. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://dx.doi.org/10.26153/tsw/2912

Chicago Manual of Style (16th Edition):

Singhal, Vivek, Ph D. “Design and development of an X-ray sensor to measure the density and flow rate of drilling fluids in high pressure lines.” 2019. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://dx.doi.org/10.26153/tsw/2912.

MLA Handbook (7th Edition):

Singhal, Vivek, Ph D. “Design and development of an X-ray sensor to measure the density and flow rate of drilling fluids in high pressure lines.” 2019. Web. 06 Dec 2019.

Vancouver:

Singhal, Vivek PD. Design and development of an X-ray sensor to measure the density and flow rate of drilling fluids in high pressure lines. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2019. [cited 2019 Dec 06]. Available from: http://dx.doi.org/10.26153/tsw/2912.

Council of Science Editors:

Singhal, Vivek PD. Design and development of an X-ray sensor to measure the density and flow rate of drilling fluids in high pressure lines. [Doctoral Dissertation]. University of Texas – Austin; 2019. Available from: http://dx.doi.org/10.26153/tsw/2912


University of Texas – Austin

7. -0101-0406. Algorithm-aided decision-making in reservoir management.

Degree: PhD, Petroleum Engineering, 2019, University of Texas – Austin

 Sound reservoir management involves making decisions in the presence of uncertainty and complexity. Because projects handled in the oil and gas industry are often highly… (more)

Subjects/Keywords: Decision analysis; Reservoir management

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APA (6th Edition):

-0101-0406. (2019). Algorithm-aided decision-making in reservoir management. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://dx.doi.org/10.26153/tsw/2917

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Chicago Manual of Style (16th Edition):

-0101-0406. “Algorithm-aided decision-making in reservoir management.” 2019. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://dx.doi.org/10.26153/tsw/2917.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

MLA Handbook (7th Edition):

-0101-0406. “Algorithm-aided decision-making in reservoir management.” 2019. Web. 06 Dec 2019.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Vancouver:

-0101-0406. Algorithm-aided decision-making in reservoir management. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2019. [cited 2019 Dec 06]. Available from: http://dx.doi.org/10.26153/tsw/2917.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Council of Science Editors:

-0101-0406. Algorithm-aided decision-making in reservoir management. [Doctoral Dissertation]. University of Texas – Austin; 2019. Available from: http://dx.doi.org/10.26153/tsw/2917

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete


University of Texas – Austin

8. Arsalan, Naveed. Characterization of surface energetics for understanding wettability and asphaltene deposition in the wellbore.

Degree: PhD, Petroleum Engineering, 2015, University of Texas – Austin

 The fundamental forces of adhesion are responsible for the spreading of fluids such as crude oil/brine on the reservoir rock surface. These physico-chemical interactions determine… (more)

Subjects/Keywords: Surface free energy; Wettability; Asphaltene; Inverse gas chromatography; Sandstones; Carbonates

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APA (6th Edition):

Arsalan, N. (2015). Characterization of surface energetics for understanding wettability and asphaltene deposition in the wellbore. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/63909

Chicago Manual of Style (16th Edition):

Arsalan, Naveed. “Characterization of surface energetics for understanding wettability and asphaltene deposition in the wellbore.” 2015. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/63909.

MLA Handbook (7th Edition):

Arsalan, Naveed. “Characterization of surface energetics for understanding wettability and asphaltene deposition in the wellbore.” 2015. Web. 06 Dec 2019.

Vancouver:

Arsalan N. Characterization of surface energetics for understanding wettability and asphaltene deposition in the wellbore. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2015. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/63909.

Council of Science Editors:

Arsalan N. Characterization of surface energetics for understanding wettability and asphaltene deposition in the wellbore. [Doctoral Dissertation]. University of Texas – Austin; 2015. Available from: http://hdl.handle.net/2152/63909


University of Texas – Austin

9. Ren, Bo. Local capillary trapping and permeability-retarded accumulation during geologic carbon sequestration.

Degree: PhD, Petroleum Engineering, 2017, University of Texas – Austin

 Safe storage of CO2 in saline aquifers depends on CO2 migration rate, accumulation, and trapping inside saline aquifers that have intrinsic heterogeneity. This heterogeneity can… (more)

Subjects/Keywords: Local capillary trapping; Permeability-retarded accumulation; Geologic carbon sequestration; Buoyant flow

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APA (6th Edition):

Ren, B. (2017). Local capillary trapping and permeability-retarded accumulation during geologic carbon sequestration. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/62236

Chicago Manual of Style (16th Edition):

Ren, Bo. “Local capillary trapping and permeability-retarded accumulation during geologic carbon sequestration.” 2017. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/62236.

MLA Handbook (7th Edition):

Ren, Bo. “Local capillary trapping and permeability-retarded accumulation during geologic carbon sequestration.” 2017. Web. 06 Dec 2019.

Vancouver:

Ren B. Local capillary trapping and permeability-retarded accumulation during geologic carbon sequestration. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2017. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/62236.

Council of Science Editors:

Ren B. Local capillary trapping and permeability-retarded accumulation during geologic carbon sequestration. [Doctoral Dissertation]. University of Texas – Austin; 2017. Available from: http://hdl.handle.net/2152/62236


University of Texas – Austin

10. Shin, Jeong-Heon. Scale effects on the latent heat of phase change & the effect of dynamic contact angles on dynamic capillary pressure: Scale effects on the latent heat of phase change and the effect of dynamic contact angles on dynamic capillary pressure.

Degree: PhD, Mechanical Engineering, 2014, University of Texas – Austin

 Surface tension is an important material property that affects the behavior of micro/nano size thermal-fluid systems. In this dissertation, I investigate how surface tension affects… (more)

Subjects/Keywords: Phase change; Latent heat; Nano; Surface energy; Capillary pressure

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APA (6th Edition):

Shin, J. (2014). Scale effects on the latent heat of phase change & the effect of dynamic contact angles on dynamic capillary pressure: Scale effects on the latent heat of phase change and the effect of dynamic contact angles on dynamic capillary pressure. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/46515

Chicago Manual of Style (16th Edition):

Shin, Jeong-Heon. “Scale effects on the latent heat of phase change & the effect of dynamic contact angles on dynamic capillary pressure: Scale effects on the latent heat of phase change and the effect of dynamic contact angles on dynamic capillary pressure.” 2014. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/46515.

MLA Handbook (7th Edition):

Shin, Jeong-Heon. “Scale effects on the latent heat of phase change & the effect of dynamic contact angles on dynamic capillary pressure: Scale effects on the latent heat of phase change and the effect of dynamic contact angles on dynamic capillary pressure.” 2014. Web. 06 Dec 2019.

Vancouver:

Shin J. Scale effects on the latent heat of phase change & the effect of dynamic contact angles on dynamic capillary pressure: Scale effects on the latent heat of phase change and the effect of dynamic contact angles on dynamic capillary pressure. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2014. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/46515.

Council of Science Editors:

Shin J. Scale effects on the latent heat of phase change & the effect of dynamic contact angles on dynamic capillary pressure: Scale effects on the latent heat of phase change and the effect of dynamic contact angles on dynamic capillary pressure. [Doctoral Dissertation]. University of Texas – Austin; 2014. Available from: http://hdl.handle.net/2152/46515


University of Texas – Austin

11. Darnell, Kristopher Nickolas. Phase behavior and the interaction of multiple gas molecules in hydrate-dominated geological flow processes.

Degree: PhD, Geological Sciences, 2018, University of Texas – Austin

 Hydrate is a non-stoichiometric, ice-like solid compound of water and gas molecules that forms at low temperatures and high pressures. The stability of a particular… (more)

Subjects/Keywords: Hydrate; Multiphase flow; Thermodynamics

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APA (6th Edition):

Darnell, K. N. (2018). Phase behavior and the interaction of multiple gas molecules in hydrate-dominated geological flow processes. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/65473

Chicago Manual of Style (16th Edition):

Darnell, Kristopher Nickolas. “Phase behavior and the interaction of multiple gas molecules in hydrate-dominated geological flow processes.” 2018. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/65473.

MLA Handbook (7th Edition):

Darnell, Kristopher Nickolas. “Phase behavior and the interaction of multiple gas molecules in hydrate-dominated geological flow processes.” 2018. Web. 06 Dec 2019.

Vancouver:

Darnell KN. Phase behavior and the interaction of multiple gas molecules in hydrate-dominated geological flow processes. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2018. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/65473.

Council of Science Editors:

Darnell KN. Phase behavior and the interaction of multiple gas molecules in hydrate-dominated geological flow processes. [Doctoral Dissertation]. University of Texas – Austin; 2018. Available from: http://hdl.handle.net/2152/65473


University of Texas – Austin

12. Mirabolghasemi, Maryam. Micro-scale modeling of formation damage.

Degree: PhD, Petroleum Engineering, 2017, University of Texas – Austin

 Loss of formation permeability often occurs during drilling, produced water re-injection, perforation, and CO₂ injection for subsurface storage. Formation permeability loss might significantly decrease wells'… (more)

Subjects/Keywords: Formation damage; Straining; Grain crushing; Micro-scale modeling

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APA (6th Edition):

Mirabolghasemi, M. (2017). Micro-scale modeling of formation damage. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/62944

Chicago Manual of Style (16th Edition):

Mirabolghasemi, Maryam. “Micro-scale modeling of formation damage.” 2017. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/62944.

MLA Handbook (7th Edition):

Mirabolghasemi, Maryam. “Micro-scale modeling of formation damage.” 2017. Web. 06 Dec 2019.

Vancouver:

Mirabolghasemi M. Micro-scale modeling of formation damage. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2017. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/62944.

Council of Science Editors:

Mirabolghasemi M. Micro-scale modeling of formation damage. [Doctoral Dissertation]. University of Texas – Austin; 2017. Available from: http://hdl.handle.net/2152/62944


University of Texas – Austin

13. -7219-1606. Gooie to kablooie : the partial melting of planetary interiors.

Degree: PhD, Geological Sciences, 2017, University of Texas – Austin

 The melting and subsequent extraction of molten materials from the Earth's mantle is the subject of much scrutiny, yet remains poorly understood. Volcanism and magmatism… (more)

Subjects/Keywords: Magma; Melt migration; Geophysics; Geochemistry

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APA (6th Edition):

-7219-1606. (2017). Gooie to kablooie : the partial melting of planetary interiors. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/62600

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Chicago Manual of Style (16th Edition):

-7219-1606. “Gooie to kablooie : the partial melting of planetary interiors.” 2017. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/62600.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

MLA Handbook (7th Edition):

-7219-1606. “Gooie to kablooie : the partial melting of planetary interiors.” 2017. Web. 06 Dec 2019.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Vancouver:

-7219-1606. Gooie to kablooie : the partial melting of planetary interiors. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2017. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/62600.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Council of Science Editors:

-7219-1606. Gooie to kablooie : the partial melting of planetary interiors. [Doctoral Dissertation]. University of Texas – Austin; 2017. Available from: http://hdl.handle.net/2152/62600

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete


University of Texas – Austin

14. -0539-9914. Scaling of solutal convection in porous media.

Degree: PhD, Petroleum Engineering, 2017, University of Texas – Austin

 Convective dissolution trapping is an important mechanism for CO₂ mitigation because of its high security and long-term storage capacity. This process is a problem of… (more)

Subjects/Keywords: Solutal convection in porous media; Convective dissolution; Convection; Dissolution; Porous media; Dispersion; Mechanical dispersion; Transverse dispersion; Molecular diffusion; Experiments in porous media; Direct numerical simulation; CO2 sequestration; CO2 convective dissolution trapping; CO2 dissolution trapping; Pattern formation; Symmetry breaking; Convection-diffusion; Longitudinal dispersion; CO₂ sequestration; CO₂ convective dissolution trapping; CO₂ dissolution trapping

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APA (6th Edition):

-0539-9914. (2017). Scaling of solutal convection in porous media. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/68164

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Chicago Manual of Style (16th Edition):

-0539-9914. “Scaling of solutal convection in porous media.” 2017. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/68164.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

MLA Handbook (7th Edition):

-0539-9914. “Scaling of solutal convection in porous media.” 2017. Web. 06 Dec 2019.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Vancouver:

-0539-9914. Scaling of solutal convection in porous media. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2017. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/68164.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Council of Science Editors:

-0539-9914. Scaling of solutal convection in porous media. [Doctoral Dissertation]. University of Texas – Austin; 2017. Available from: http://hdl.handle.net/2152/68164

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete


University of Texas – Austin

15. Ghanbarzadeh, Soheil. Pore fluid percolation and flow in ductile rocks.

Degree: PhD, Petroleum Engineering, 2016, University of Texas – Austin

 Ductile rocks have capacity to deform in response to large strains without macroscopic fracturing. Such behavior may occur in rocks that did not undergo diagenesis,… (more)

Subjects/Keywords: Ductile rock; Textural equilibrium; Percolation; Dihedral angle; Fluid flow

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APA (6th Edition):

Ghanbarzadeh, S. (2016). Pore fluid percolation and flow in ductile rocks. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/47007

Chicago Manual of Style (16th Edition):

Ghanbarzadeh, Soheil. “Pore fluid percolation and flow in ductile rocks.” 2016. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/47007.

MLA Handbook (7th Edition):

Ghanbarzadeh, Soheil. “Pore fluid percolation and flow in ductile rocks.” 2016. Web. 06 Dec 2019.

Vancouver:

Ghanbarzadeh S. Pore fluid percolation and flow in ductile rocks. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2016. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/47007.

Council of Science Editors:

Ghanbarzadeh S. Pore fluid percolation and flow in ductile rocks. [Doctoral Dissertation]. University of Texas – Austin; 2016. Available from: http://hdl.handle.net/2152/47007


University of Texas – Austin

16. -9644-1086. Multifunctional foams and emulsions for subsurface applications.

Degree: PhD, Petroleum Engineering, 2018, University of Texas – Austin

 Foams and emulsions hold immense potential in assisting in the different stages of oil recovery processes such as enhanced oil recovery, drilling, and completion. This… (more)

Subjects/Keywords: Foams; Emulsions; Nanoparticles; Porous media; Conformance control; Enhanced oil recovery; Water-in-air powders; Microencapsulation; Shale stimulation; Wettability; Foam EOR; Subsurface; Surfactant

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APA (6th Edition):

-9644-1086. (2018). Multifunctional foams and emulsions for subsurface applications. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/63736

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Author name may be incomplete

Chicago Manual of Style (16th Edition):

-9644-1086. “Multifunctional foams and emulsions for subsurface applications.” 2018. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/63736.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

MLA Handbook (7th Edition):

-9644-1086. “Multifunctional foams and emulsions for subsurface applications.” 2018. Web. 06 Dec 2019.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Vancouver:

-9644-1086. Multifunctional foams and emulsions for subsurface applications. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2018. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/63736.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Council of Science Editors:

-9644-1086. Multifunctional foams and emulsions for subsurface applications. [Doctoral Dissertation]. University of Texas – Austin; 2018. Available from: http://hdl.handle.net/2152/63736

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete


University of Texas – Austin

17. -9386-4956. Analytical solutions of pressure-production tests with permanent multisensors in oil gas and water zones.

Degree: PhD, Petroleum Engineering, 2019, University of Texas – Austin

 The petroleum industry has invested millions of dollars in developing technologies for improving the monitoring methods for wells. These wells may have up to eight… (more)

Subjects/Keywords: Well-test; Partial penetrate well; Multiphase; Moving boundary

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APA (6th Edition):

-9386-4956. (2019). Analytical solutions of pressure-production tests with permanent multisensors in oil gas and water zones. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://dx.doi.org/10.26153/tsw/3102

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Chicago Manual of Style (16th Edition):

-9386-4956. “Analytical solutions of pressure-production tests with permanent multisensors in oil gas and water zones.” 2019. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://dx.doi.org/10.26153/tsw/3102.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

MLA Handbook (7th Edition):

-9386-4956. “Analytical solutions of pressure-production tests with permanent multisensors in oil gas and water zones.” 2019. Web. 06 Dec 2019.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Vancouver:

-9386-4956. Analytical solutions of pressure-production tests with permanent multisensors in oil gas and water zones. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2019. [cited 2019 Dec 06]. Available from: http://dx.doi.org/10.26153/tsw/3102.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Council of Science Editors:

-9386-4956. Analytical solutions of pressure-production tests with permanent multisensors in oil gas and water zones. [Doctoral Dissertation]. University of Texas – Austin; 2019. Available from: http://dx.doi.org/10.26153/tsw/3102

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete


University of Texas – Austin

18. Jung, Hojung. Investigation of coupled thermo-chemo-mechanical processes for safe carbon geological storage.

Degree: PhD, Petroleum Engineering, 2018, University of Texas – Austin

 Safe and permanent CO₂ storage in geological formations requires reservoir geomechanical stability. Injection of CO₂ into the subsurface changes the local pore pressure and, further,… (more)

Subjects/Keywords: Carbon sequestration; Geomechanical stability

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APA (6th Edition):

Jung, H. (2018). Investigation of coupled thermo-chemo-mechanical processes for safe carbon geological storage. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://dx.doi.org/10.26153/tsw/1339

Chicago Manual of Style (16th Edition):

Jung, Hojung. “Investigation of coupled thermo-chemo-mechanical processes for safe carbon geological storage.” 2018. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://dx.doi.org/10.26153/tsw/1339.

MLA Handbook (7th Edition):

Jung, Hojung. “Investigation of coupled thermo-chemo-mechanical processes for safe carbon geological storage.” 2018. Web. 06 Dec 2019.

Vancouver:

Jung H. Investigation of coupled thermo-chemo-mechanical processes for safe carbon geological storage. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2018. [cited 2019 Dec 06]. Available from: http://dx.doi.org/10.26153/tsw/1339.

Council of Science Editors:

Jung H. Investigation of coupled thermo-chemo-mechanical processes for safe carbon geological storage. [Doctoral Dissertation]. University of Texas – Austin; 2018. Available from: http://dx.doi.org/10.26153/tsw/1339


University of Texas – Austin

19. Doorwar, Shashvat. Understanding unstable immiscible displacement in porous media.

Degree: PhD, Petroleum Engineering, 2015, University of Texas – Austin

 Our global heavy and viscous oil reserves are immense. 70% of our current global oils reserves are viscous or heavy. For an energy secure future,… (more)

Subjects/Keywords: Viscous fingering; Up-scaling; Reservoir engineering; Unstable displacement; Viscosity ratio; Modeling; Dielectric breakdown; Micromodel; Microfluidics

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APA (6th Edition):

Doorwar, S. (2015). Understanding unstable immiscible displacement in porous media. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/31622

Chicago Manual of Style (16th Edition):

Doorwar, Shashvat. “Understanding unstable immiscible displacement in porous media.” 2015. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/31622.

MLA Handbook (7th Edition):

Doorwar, Shashvat. “Understanding unstable immiscible displacement in porous media.” 2015. Web. 06 Dec 2019.

Vancouver:

Doorwar S. Understanding unstable immiscible displacement in porous media. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2015. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/31622.

Council of Science Editors:

Doorwar S. Understanding unstable immiscible displacement in porous media. [Doctoral Dissertation]. University of Texas – Austin; 2015. Available from: http://hdl.handle.net/2152/31622


University of Texas – Austin

20. Kianinejad, Amir. Measurement and modeling of three-phase relative permeability as a function of saturation path.

Degree: PhD, Petroleum engineering, 2016, University of Texas – Austin

 Three-phase flow occurs in many petroleum recovery processes, especially during tertiary recovery. One of the most important parameters to accurately model these complex processes at… (more)

Subjects/Keywords: Three-phase; Relative permeability

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APA (6th Edition):

Kianinejad, A. (2016). Measurement and modeling of three-phase relative permeability as a function of saturation path. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/40315

Chicago Manual of Style (16th Edition):

Kianinejad, Amir. “Measurement and modeling of three-phase relative permeability as a function of saturation path.” 2016. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/40315.

MLA Handbook (7th Edition):

Kianinejad, Amir. “Measurement and modeling of three-phase relative permeability as a function of saturation path.” 2016. Web. 06 Dec 2019.

Vancouver:

Kianinejad A. Measurement and modeling of three-phase relative permeability as a function of saturation path. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2016. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/40315.

Council of Science Editors:

Kianinejad A. Measurement and modeling of three-phase relative permeability as a function of saturation path. [Doctoral Dissertation]. University of Texas – Austin; 2016. Available from: http://hdl.handle.net/2152/40315


University of Texas – Austin

21. Chang, Leonard Yujya. Prediction of microemulsion phase behavior from surfactant and co-solvent structures.

Degree: PhD, Petroleum Engineering, 2018, University of Texas – Austin

 Structure-property models were developed to predict the optimum salinity, optimum solubilization ratio, and the aqueous stability limit from the molecular structures of surfactants and co-solvents… (more)

Subjects/Keywords: EOR; Microemulsion; Structure; Phase behavior; Surfactant; Co-solvent

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APA (6th Edition):

Chang, L. Y. (2018). Prediction of microemulsion phase behavior from surfactant and co-solvent structures. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://dx.doi.org/10.26153/tsw/1385

Chicago Manual of Style (16th Edition):

Chang, Leonard Yujya. “Prediction of microemulsion phase behavior from surfactant and co-solvent structures.” 2018. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://dx.doi.org/10.26153/tsw/1385.

MLA Handbook (7th Edition):

Chang, Leonard Yujya. “Prediction of microemulsion phase behavior from surfactant and co-solvent structures.” 2018. Web. 06 Dec 2019.

Vancouver:

Chang LY. Prediction of microemulsion phase behavior from surfactant and co-solvent structures. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2018. [cited 2019 Dec 06]. Available from: http://dx.doi.org/10.26153/tsw/1385.

Council of Science Editors:

Chang LY. Prediction of microemulsion phase behavior from surfactant and co-solvent structures. [Doctoral Dissertation]. University of Texas – Austin; 2018. Available from: http://dx.doi.org/10.26153/tsw/1385


University of Texas – Austin

22. -5810-1547. Compositional changes of light hydrocarbons during migration through overburden : proxy for assessing potential leakage from Geological Carbon Storage.

Degree: PhD, Geological Sciences, 2018, University of Texas – Austin

 Light hydrocarbon compositions evolve during migration through geologic media, but our understanding of geochemical alteration is limited because of the challenges with analyzing fluids in… (more)

Subjects/Keywords: Hydrocarbon migration; Seepage

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APA (6th Edition):

-5810-1547. (2018). Compositional changes of light hydrocarbons during migration through overburden : proxy for assessing potential leakage from Geological Carbon Storage. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/63852

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Author name may be incomplete

Chicago Manual of Style (16th Edition):

-5810-1547. “Compositional changes of light hydrocarbons during migration through overburden : proxy for assessing potential leakage from Geological Carbon Storage.” 2018. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/63852.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

MLA Handbook (7th Edition):

-5810-1547. “Compositional changes of light hydrocarbons during migration through overburden : proxy for assessing potential leakage from Geological Carbon Storage.” 2018. Web. 06 Dec 2019.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Vancouver:

-5810-1547. Compositional changes of light hydrocarbons during migration through overburden : proxy for assessing potential leakage from Geological Carbon Storage. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2018. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/63852.

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

Council of Science Editors:

-5810-1547. Compositional changes of light hydrocarbons during migration through overburden : proxy for assessing potential leakage from Geological Carbon Storage. [Doctoral Dissertation]. University of Texas – Austin; 2018. Available from: http://hdl.handle.net/2152/63852

Note: this citation may be lacking information needed for this citation format:
Author name may be incomplete

23. Liang, Yu, active 21st century. Experimental study of convective dissolution of carbon dioxide in porous media.

Degree: MSin Engineering, Petroleum Engineering, 2014, University of Texas – Austin

 Geological carbon dioxide (CO₂) capture and storage in geological formations has the potential to reduce anthropogenic emissions. The viability of technology depends on the long-term… (more)

Subjects/Keywords: CO₂ sequestration; CO₂ dissolution trapping; Multiphase flow; Porous media; Convection

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APA (6th Edition):

Liang, Yu, a. 2. c. (2014). Experimental study of convective dissolution of carbon dioxide in porous media. (Masters Thesis). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/28295

Chicago Manual of Style (16th Edition):

Liang, Yu, active 21st century. “Experimental study of convective dissolution of carbon dioxide in porous media.” 2014. Masters Thesis, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/28295.

MLA Handbook (7th Edition):

Liang, Yu, active 21st century. “Experimental study of convective dissolution of carbon dioxide in porous media.” 2014. Web. 06 Dec 2019.

Vancouver:

Liang, Yu a2c. Experimental study of convective dissolution of carbon dioxide in porous media. [Internet] [Masters thesis]. University of Texas – Austin; 2014. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/28295.

Council of Science Editors:

Liang, Yu a2c. Experimental study of convective dissolution of carbon dioxide in porous media. [Masters Thesis]. University of Texas – Austin; 2014. Available from: http://hdl.handle.net/2152/28295

24. Mirzaei Galeh Kalaei, Mohammad. Imbibition of anionic surfactant solution into oil-wet matrix in fractured reservoirs.

Degree: PhD, Petroleum Engineering, 2013, University of Texas – Austin

 Water-flooding in water-wet fractured reservoirs can recover significant amounts of oil through capillary driven imbibition. Unfortunately, many of the fractured reservoirs are mixed-wet/oil-wet and water-flooding… (more)

Subjects/Keywords: Enhanced oil recovery; Imbibition; Oil-wet; Surfactant; Low IFT; Wettability; CT scan; Scaling; Capillary tube; Gravity drainage

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APA (6th Edition):

Mirzaei Galeh Kalaei, M. (2013). Imbibition of anionic surfactant solution into oil-wet matrix in fractured reservoirs. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/21505

Chicago Manual of Style (16th Edition):

Mirzaei Galeh Kalaei, Mohammad. “Imbibition of anionic surfactant solution into oil-wet matrix in fractured reservoirs.” 2013. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/21505.

MLA Handbook (7th Edition):

Mirzaei Galeh Kalaei, Mohammad. “Imbibition of anionic surfactant solution into oil-wet matrix in fractured reservoirs.” 2013. Web. 06 Dec 2019.

Vancouver:

Mirzaei Galeh Kalaei M. Imbibition of anionic surfactant solution into oil-wet matrix in fractured reservoirs. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2013. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/21505.

Council of Science Editors:

Mirzaei Galeh Kalaei M. Imbibition of anionic surfactant solution into oil-wet matrix in fractured reservoirs. [Doctoral Dissertation]. University of Texas – Austin; 2013. Available from: http://hdl.handle.net/2152/21505

25. Huynh, Uyen T. Surfactant characterization to improve water recovery in shale gas reservoirs.

Degree: MSin Engineering, Petroleum Engineering, 2013, University of Texas – Austin

 After a fracturing job in a shale reservoir, only a fraction of injected water is recovered. Water is trapped inside the reservoir and reduces the… (more)

Subjects/Keywords: Hydraulic; Fracturing; Surfactant; Shale; CO2; Shale gas; Cationic; Ethomeen

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APA (6th Edition):

Huynh, U. T. (2013). Surfactant characterization to improve water recovery in shale gas reservoirs. (Masters Thesis). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/23798

Chicago Manual of Style (16th Edition):

Huynh, Uyen T. “Surfactant characterization to improve water recovery in shale gas reservoirs.” 2013. Masters Thesis, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/23798.

MLA Handbook (7th Edition):

Huynh, Uyen T. “Surfactant characterization to improve water recovery in shale gas reservoirs.” 2013. Web. 06 Dec 2019.

Vancouver:

Huynh UT. Surfactant characterization to improve water recovery in shale gas reservoirs. [Internet] [Masters thesis]. University of Texas – Austin; 2013. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/23798.

Council of Science Editors:

Huynh UT. Surfactant characterization to improve water recovery in shale gas reservoirs. [Masters Thesis]. University of Texas – Austin; 2013. Available from: http://hdl.handle.net/2152/23798

26. Zhu, Di, 1987-. Simultaneous phase-stability/-split computation for multiphase oil-displacement simulation.

Degree: PhD, Petroleum Engineering, 2018, University of Texas – Austin

 Solvent injection is a widely used method for enhanced oil recovery. Phase behavior of reservoir-oil/injection-gas mixtures should be effectively used for successful implementation of solvent… (more)

Subjects/Keywords: Simultaneous phase-stability/-split computation; Multiphase oil-displacement

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APA (6th Edition):

Zhu, Di, 1. (2018). Simultaneous phase-stability/-split computation for multiphase oil-displacement simulation. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/63818

Chicago Manual of Style (16th Edition):

Zhu, Di, 1987-. “Simultaneous phase-stability/-split computation for multiphase oil-displacement simulation.” 2018. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/63818.

MLA Handbook (7th Edition):

Zhu, Di, 1987-. “Simultaneous phase-stability/-split computation for multiphase oil-displacement simulation.” 2018. Web. 06 Dec 2019.

Vancouver:

Zhu, Di 1. Simultaneous phase-stability/-split computation for multiphase oil-displacement simulation. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2018. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/63818.

Council of Science Editors:

Zhu, Di 1. Simultaneous phase-stability/-split computation for multiphase oil-displacement simulation. [Doctoral Dissertation]. University of Texas – Austin; 2018. Available from: http://hdl.handle.net/2152/63818

27. Zhu, Chunxiao. NMR longitudinal surface relaxation phenomena of metal oxide nanoparticles in porous media.

Degree: PhD, Petroleum Engineering, 2017, University of Texas – Austin

 1H Nuclear Magnetic Resonance (NMR) has long been applied in downhole logging and laboratory analyses to investigate pore size distributions of rocks through correlation with… (more)

Subjects/Keywords: NMR; Longitudinal relaxation; Nanoparticles; Porous media; Petrophysics

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APA (6th Edition):

Zhu, C. (2017). NMR longitudinal surface relaxation phenomena of metal oxide nanoparticles in porous media. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/62229

Chicago Manual of Style (16th Edition):

Zhu, Chunxiao. “NMR longitudinal surface relaxation phenomena of metal oxide nanoparticles in porous media.” 2017. Doctoral Dissertation, University of Texas – Austin. Accessed December 06, 2019. http://hdl.handle.net/2152/62229.

MLA Handbook (7th Edition):

Zhu, Chunxiao. “NMR longitudinal surface relaxation phenomena of metal oxide nanoparticles in porous media.” 2017. Web. 06 Dec 2019.

Vancouver:

Zhu C. NMR longitudinal surface relaxation phenomena of metal oxide nanoparticles in porous media. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2017. [cited 2019 Dec 06]. Available from: http://hdl.handle.net/2152/62229.

Council of Science Editors:

Zhu C. NMR longitudinal surface relaxation phenomena of metal oxide nanoparticles in porous media. [Doctoral Dissertation]. University of Texas – Austin; 2017. Available from: http://hdl.handle.net/2152/62229

.