subject:(Capillary Pressure)

Texas A&M University

1. Apisaksirikul, Sarin. The Development and Application of a New Semi-Analytical Model to Estimate Permeability from Mercury Injection Capillary Pressure.

Degree: MS, Petroleum Engineering, 2016, Texas A&M University

URL: http://hdl.handle.net/1969.1/157141

► In 2005 Huet proposed a semi-analytical model to correlate between rock permeability and capillary pressure data. The model was proposed with the intention to be… (more)

▼ In 2005 Huet proposed a semi-analytical model to correlate between rock permeability and capillary pressure data. The model was proposed with the intention to be a "universal" model where the correlation was unique over a wide range of rock types. The objectives of this study are to verify the power-law relationship between permeability and the mercury injection capillary pressure (MICP) parameters in Huet's semi-analytical model and to propose a new correlation to predict permeability from the MICP data. We used a data set consisting of 323 samples from different lithologies including tight, sandstone and carbonate reservoirs. The semi-analytical (Huet) model correlates permeability with porosity (), irreducible wetting phase saturation (Swi), displacement pressure (pd), and the pore-size distribution index () obtained from MICP data. The resulting correlation equation generated in this work shows very good coherence for permeabilities higher than 1 md and reasonably good coherence for permeabilities less than 1 md. In this work we have refitted the Huet model to our database of 323 samples and over the entire range of permeabilities considered (i.e., 1x10^-7 to 1x10⁴ md), 95 percent of the data are related to the proposed model by a factor of 9.1 or less, and 58 percent of the data are related to the proposed model by a factor of 2 or less. When the data are "partitioned," we find that our refitted model has a 95% prediction interval within a factor of 3.97 for permeability values greater than 1 md and 12.70 for permeability values less than 1 md. We also showed in this work that our proposed model outperformed the Swanson model to predict permeability from MICP data. In addition to the statistical work, we performed analytical derivations to establish an analytical relationship between the semi-analytical (Huet) model and the Swanson model. Our derivation results support the application of the semi-analytical model as a viable (and possibly superior) alternative to the Swanson model. Our analytical work also provides an insight into the viability of the Swanson model, which was developed empirically. Based on this derivation, we propose a new method to determine the Brooks-Corey capillary pressure model parameters as an alternative to the regression method. In short, this work has confirmed the power-law relationship between permeability and the mercury injection capillary pressure data to be valid for both sandstone and carbonate reservoirs. The new correlation model proposed should provide an improvement for the prediction of permeability from the mercury injection capillary pressure data. This work also holds promise in relating the Huet semi-analytical model to the Swanson empirical model directly, and we expect that (eventually) a type of "hybrid" model will evolve which will include the influence of both the Brooks-Corey and the Swanson capillary pressure models. Advisors/Committee Members: Blasingame, Thomas A. (advisor), Akkutlu, Yucel I. (committee member), Barrufet, Maria A. (committee member).

Subjects/Keywords: permeability; capillary pressure; MICP

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APA (6^th Edition):

Apisaksirikul, S. (2016). The Development and Application of a New Semi-Analytical Model to Estimate Permeability from Mercury Injection Capillary Pressure. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/157141

Chicago Manual of Style (16^th Edition):

Apisaksirikul, Sarin. “The Development and Application of a New Semi-Analytical Model to Estimate Permeability from Mercury Injection Capillary Pressure.” 2016. Masters Thesis, Texas A&M University. Accessed January 24, 2021. http://hdl.handle.net/1969.1/157141.

MLA Handbook (7^th Edition):

Apisaksirikul, Sarin. “The Development and Application of a New Semi-Analytical Model to Estimate Permeability from Mercury Injection Capillary Pressure.” 2016. Web. 24 Jan 2021.

Vancouver:

Apisaksirikul S. The Development and Application of a New Semi-Analytical Model to Estimate Permeability from Mercury Injection Capillary Pressure. [Internet] [Masters thesis]. Texas A&M University; 2016. [cited 2021 Jan 24]. Available from: http://hdl.handle.net/1969.1/157141.

Council of Science Editors:

Apisaksirikul S. The Development and Application of a New Semi-Analytical Model to Estimate Permeability from Mercury Injection Capillary Pressure. [Masters Thesis]. Texas A&M University; 2016. Available from: http://hdl.handle.net/1969.1/157141

Texas A&M University

2. Li, Bo. Capillary Pressure in Nanopores: Deviation from Young-Laplace Equation.

Degree: MS, Petroleum Engineering, 2017, Texas A&M University

URL: http://hdl.handle.net/1969.1/174760

► Recent studies on multi-phase fluids in nanoscale capillaries indicated that the capillary wall-fluid interactions could play a dominant role on the co-existence of the phases,… (more)

Subjects/Keywords: Capillary Pressure; Nanopores; Young-Laplace Equation; MICP

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Li, B. (2017). Capillary Pressure in Nanopores: Deviation from Young-Laplace Equation. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/174760

Chicago Manual of Style (16^th Edition):

Li, Bo. “Capillary Pressure in Nanopores: Deviation from Young-Laplace Equation.” 2017. Masters Thesis, Texas A&M University. Accessed January 24, 2021. http://hdl.handle.net/1969.1/174760.

MLA Handbook (7^th Edition):

Li, Bo. “Capillary Pressure in Nanopores: Deviation from Young-Laplace Equation.” 2017. Web. 24 Jan 2021.

Vancouver:

Li B. Capillary Pressure in Nanopores: Deviation from Young-Laplace Equation. [Internet] [Masters thesis]. Texas A&M University; 2017. [cited 2021 Jan 24]. Available from: http://hdl.handle.net/1969.1/174760.

Council of Science Editors:

Li B. Capillary Pressure in Nanopores: Deviation from Young-Laplace Equation. [Masters Thesis]. Texas A&M University; 2017. Available from: http://hdl.handle.net/1969.1/174760

Delft University of Technology

3. Mikati, Ibrahim (author). Multiphase flow in tight formations.

Degree: 2018, Delft University of Technology

URL: http://resolver.tudelft.nl/uuid:cb4c6d30-588f-4d9c-a619-5bb205c87a35

► Given the substantial growth of the shale industry over the last decade, understanding flow in confined spaces will play a primordial role in the future… (more)

▼ Given the substantial growth of the shale industry over the last decade, understanding flow in confined spaces will play a primordial role in the future of the upstream petroleum sector. Most compositional simulators are designed for standard (unconfined) reservoirs. Additional physical phenomena occurring in confined spaces such as capillary pressure, diffusion and adsorption are not taken into account. Moreover, most studies conducted on this topic only focus on shale gas, without regards to the presence of a liquid phase. This thesis focuses on the effects of capillary pressure on a multiphase flow and describes the modified production profiles. Recent studies have shown that elevated capillary pressure in confined spaces modifies the phase behavior of the hydrocarbon mixture, namely causing a reduction of the bubble point, which in turn affects the oil density and viscosity. These modifications will alter well produc- tion dynamics. Standard compositional simulators couple a mass balance equation with conservation laws and thermodynamic equilibrium, which comes in the form of a nonlinear constraint describ- ing the equality of chemical potentials. This research work replaces the last condition with a modified K-value constraint. The K-value is simply the ratio of a component’s composition in its vapor phase to its liquid phase. The latter is specific to the pressure, temperature and the hydrocarbon sample’s molar composition; and is derived from equations of state (EOS) which are employed to describe the phase behavior of a system. Capillarity is introduced in the K-value by adding the Parachor model, which determines the interfacial tension and the Laplace equation to the EOS derivation. The modified K-values are incorporated into Stanford’s Automatic Differentiation General Purpose Research Simulator (ADGPRS) based on a fully implicit approach. Other necessary modifications were made to include the effects of heterogeneity in the system. Simulations were ran in both simple one-dimensional reservoirs and more complex fractured models de- picting fractured shale reservoirs and compared to the production results generated by stan- dard compositional model. Advisors/Committee Members: Voskov, Denis (mentor), Delft University of Technology (degree granting institution).

Subjects/Keywords: shale; capillary pressure; K-value; confinement

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APA (6^th Edition):

Mikati, I. (. (2018). Multiphase flow in tight formations. (Masters Thesis). Delft University of Technology. Retrieved from http://resolver.tudelft.nl/uuid:cb4c6d30-588f-4d9c-a619-5bb205c87a35

Chicago Manual of Style (16^th Edition):

Mikati, Ibrahim (author). “Multiphase flow in tight formations.” 2018. Masters Thesis, Delft University of Technology. Accessed January 24, 2021. http://resolver.tudelft.nl/uuid:cb4c6d30-588f-4d9c-a619-5bb205c87a35.

MLA Handbook (7^th Edition):

Mikati, Ibrahim (author). “Multiphase flow in tight formations.” 2018. Web. 24 Jan 2021.

Vancouver:

Mikati I(. Multiphase flow in tight formations. [Internet] [Masters thesis]. Delft University of Technology; 2018. [cited 2021 Jan 24]. Available from: http://resolver.tudelft.nl/uuid:cb4c6d30-588f-4d9c-a619-5bb205c87a35.

Council of Science Editors:

Mikati I(. Multiphase flow in tight formations. [Masters Thesis]. Delft University of Technology; 2018. Available from: http://resolver.tudelft.nl/uuid:cb4c6d30-588f-4d9c-a619-5bb205c87a35

Georgia Tech

4. Silva, James Emanuel. PNIPAM hydrogel micro/nanostructures for bulk fluid and droplet control.

Degree: MS, Mechanical Engineering, 2014, Georgia Tech

URL: http://hdl.handle.net/1853/54252

► Poly(N-isopropylacrylamide) (PNIPAM) belongs to a class of stimuli-responsive materials known as “smart” polymers. When cast in the form of a hydrogel, PNIPAM’s lower critical solution… (more)

Subjects/Keywords: Hydrogel; Capillary pressure; Stick and slip; PNIPAM

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Silva, J. E. (2014). PNIPAM hydrogel micro/nanostructures for bulk fluid and droplet control. (Masters Thesis). Georgia Tech. Retrieved from http://hdl.handle.net/1853/54252

Chicago Manual of Style (16^th Edition):

Silva, James Emanuel. “PNIPAM hydrogel micro/nanostructures for bulk fluid and droplet control.” 2014. Masters Thesis, Georgia Tech. Accessed January 24, 2021. http://hdl.handle.net/1853/54252.

MLA Handbook (7^th Edition):

Silva, James Emanuel. “PNIPAM hydrogel micro/nanostructures for bulk fluid and droplet control.” 2014. Web. 24 Jan 2021.

Vancouver:

Silva JE. PNIPAM hydrogel micro/nanostructures for bulk fluid and droplet control. [Internet] [Masters thesis]. Georgia Tech; 2014. [cited 2021 Jan 24]. Available from: http://hdl.handle.net/1853/54252.

Council of Science Editors:

Silva JE. PNIPAM hydrogel micro/nanostructures for bulk fluid and droplet control. [Masters Thesis]. Georgia Tech; 2014. Available from: http://hdl.handle.net/1853/54252

University of New South Wales

5. Yanici, Sefer. Laboratory analysis of the predictive value of image-based computations for resistivity index.

Degree: Petroleum Engineering, 2012, University of New South Wales

URL: http://handle.unsw.edu.au/1959.4/52267 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:10939/SOURCE01?view=true

► This thesis presents a numerical and experimental investigation of resistivity index (RI)at low water saturations. A novel analysis of micro-CT images of small rock samples… (more)

▼ This thesis presents a numerical and experimental investigation of resistivity index (RI)at low water saturations. A novel analysis of micro-CT images of small rock samples iscombined with laboratory measurements to examine the predictive value of imagebasedcomputations of RI. Experimentally measured porosity, formation factor,capillary pressure (Pc) and RI are compared with image-based computations using thesame rock sample for both imaging and laboratory measurements. The fluid systemsused are 2wt% NaCl brine and air. The porous plate and centrifuge methods are used tomeasure Pc and RI at ambient conditions. Two carbonate samples from the Middle Eastand two outcrop sandstone samples (Fontainebleau and Bentheimer) are investigated.Three of the samples are homogeneous and one of the carbonate samples isheterogeneous. The effects of injection boundaries on image based computations ofsingle and multiphase flow properties of the rock samples are investigated numerically.The RI of Fontainebleau and Bentheimer sandstone is studied at water saturations aslow as 10%.The laboratory measurements show that it is possible to conduct reasonable tests on thesmall rock samples which are used for image analysis. For homogeneous rocks thesemeasurements compare well with measurements made using conventional size coresand the measurements are in reasonable agreement with image-based computations.Simulations are in good agreement with experimental measurements of capillarydrainage RI using the porous plate method at water saturations as low as 10%. However,this agreement is a result of careful treatment of discretisation effects. Fontainebleausandstone exhibits a percolating network of grain contacts, while the high-porosityBentheimer sandstone does not. It is shown that this difference in the topologicalconnection of conductive films at low water saturations is responsible for the non-Archie behaviour of Fontainebleau sandstone. It is shown that grain contactconductivity needs to be attributed to the grain contacts in Fontainebleau sandstone inorder to reconcile experiments and computations. Conductive films organised aspendular rings around grain contacts are shown to be insufficient to explain this result. Advisors/Committee Members: Cinar, Yildiray, Petroleum Engineering, Faculty of Engineering, UNSW, Arns, Christoph, Petroleum Engineering, Faculty of Engineering, UNSW, Pinczewski, Val, Petroleum Engineering, Faculty of Engineering, UNSW.

Subjects/Keywords: Capillary Pressure; Micro-CT image; Resistivity Index

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APA (6^th Edition):

Yanici, S. (2012). Laboratory analysis of the predictive value of image-based computations for resistivity index. (Doctoral Dissertation). University of New South Wales. Retrieved from http://handle.unsw.edu.au/1959.4/52267 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:10939/SOURCE01?view=true

Chicago Manual of Style (16^th Edition):

Yanici, Sefer. “Laboratory analysis of the predictive value of image-based computations for resistivity index.” 2012. Doctoral Dissertation, University of New South Wales. Accessed January 24, 2021. http://handle.unsw.edu.au/1959.4/52267 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:10939/SOURCE01?view=true.

MLA Handbook (7^th Edition):

Yanici, Sefer. “Laboratory analysis of the predictive value of image-based computations for resistivity index.” 2012. Web. 24 Jan 2021.

Vancouver:

Yanici S. Laboratory analysis of the predictive value of image-based computations for resistivity index. [Internet] [Doctoral dissertation]. University of New South Wales; 2012. [cited 2021 Jan 24]. Available from: http://handle.unsw.edu.au/1959.4/52267 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:10939/SOURCE01?view=true.

Council of Science Editors:

Yanici S. Laboratory analysis of the predictive value of image-based computations for resistivity index. [Doctoral Dissertation]. University of New South Wales; 2012. Available from: http://handle.unsw.edu.au/1959.4/52267 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:10939/SOURCE01?view=true

University of Texas – Austin

6. Saadatpoor, Ehsan, 1982-. Local capillary trapping in geological carbon storage.

Degree: PhD, Petroleum Engineering, 2012, University of Texas – Austin

URL: http://hdl.handle.net/2152/18490

► After the injection of CO₂ into a subsurface formation, various storage mechanisms help immobilize the CO₂. Injection strategies that promote the buoyant movement of CO₂… (more)

▼ After the injection of CO₂ into a subsurface formation, various storage mechanisms help immobilize the CO₂. Injection strategies that promote the buoyant movement of CO₂ during the post-injection period can increase immobilization by the mechanisms of dissolution and residual phase trapping. In this work, we argue that the heterogeneity intrinsic to sedimentary rocks gives rise to another category of trapping, which we call local capillary trapping. In a heterogeneous storage formation where capillary entry pressure of the rock is correlated with other petrophysical properties, numerous local capillary barriers exist and can trap rising CO₂ below them. The size of barriers depends on the correlation length, i.e., the characteristic size of regions having similar values of capillary entry pressure. This dissertation evaluates the dynamics of the local capillary trapping and its effectiveness to add an element of increased capacity and containment security in carbon storage in heterogeneous permeable media. The overall objective is to obtain the rigorous assessment of the amount and extent of local capillary trapping expected to occur in typical storage formations. A series of detailed numerical simulations are used to quantify the amount of local capillary trapping and to study the effect of local capillary barriers on CO₂ leakage from the storage formation. Also, a research code is developed for finding clusters of local capillary trapping from capillary entry pressure field based on the assumption that in post-injection period the viscous forces are negligible and the process is governed solely by capillary forces. The code is used to make a quantitative assessment of an upper bound for local capillary trapping capacity in heterogeneous domains using the geologic data, which is especially useful for field projects since it is very fast compared to flow simulation. The results show that capillary heterogeneity decreases the threshold capacity for non-leakable storage of CO₂. However, in cases where the injected volume is more than threshold capacity, capillary heterogeneity adds an element of security to the structural seal, regardless of how CO₂ is accumulated under the seal, either by injection or by buoyancy. In other words, ignoring heterogeneity gives the worst-case estimate of the risk. Nevertheless, during a potential leakage through failed seals, a range of CO₂ leakage amounts may occur depending on heterogeneity and the location of the leak. In geologic CO₂ storage in typical saline aquifers, the local capillary trapping can result in large volumes that are sufficiently trapped and immobilized. In fact, this behavior has significant implications for estimates of permanence of storage, for assessments of leakage rates, and for predicting ultimate consequences of leakage. Advisors/Committee Members: Bryant, Steven L. (advisor), Sepehrnoori, Kamy, 1951- (advisor).

Subjects/Keywords: CO₂; Geological carbon storage; Capillary pressure; Heterogeneous; Scaling; Local capillary trapping; Leakage; Upscaling

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Saadatpoor, Ehsan, 1. (2012). Local capillary trapping in geological carbon storage. (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/18490

Chicago Manual of Style (16^th Edition):

Saadatpoor, Ehsan, 1982-. “Local capillary trapping in geological carbon storage.” 2012. Doctoral Dissertation, University of Texas – Austin. Accessed January 24, 2021. http://hdl.handle.net/2152/18490.

MLA Handbook (7^th Edition):

Saadatpoor, Ehsan, 1982-. “Local capillary trapping in geological carbon storage.” 2012. Web. 24 Jan 2021.

Vancouver:

Saadatpoor, Ehsan 1. Local capillary trapping in geological carbon storage. [Internet] [Doctoral dissertation]. University of Texas – Austin; 2012. [cited 2021 Jan 24]. Available from: http://hdl.handle.net/2152/18490.

Council of Science Editors:

Saadatpoor, Ehsan 1. Local capillary trapping in geological carbon storage. [Doctoral Dissertation]. University of Texas – Austin; 2012. Available from: http://hdl.handle.net/2152/18490

University of Alberta

7. Liu,Ming. BEHAVIOR OF SHALE CAPROCK UNDER EXPOSURE TO SUPERCRITICAL CO2.

Degree: MS, Department of Civil and Environmental Engineering, 2013, University of Alberta

URL: https://era.library.ualberta.ca/files/p8418n908

► Batch reaction tests were conducted on Lea Park shale from Pembina Cardium Field in Alberta to investigate geochemical alterations induced by exposing brine/CO2 mixtures at… (more)

Subjects/Keywords: Carbon Storage, Shale, Pemeability, Capillary Pressure, Batch Reaction

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APA (6^th Edition):

Liu,Ming. (2013). BEHAVIOR OF SHALE CAPROCK UNDER EXPOSURE TO SUPERCRITICAL CO2. (Masters Thesis). University of Alberta. Retrieved from https://era.library.ualberta.ca/files/p8418n908

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

Chicago Manual of Style (16^th Edition):

Liu,Ming. “BEHAVIOR OF SHALE CAPROCK UNDER EXPOSURE TO SUPERCRITICAL CO2.” 2013. Masters Thesis, University of Alberta. Accessed January 24, 2021. https://era.library.ualberta.ca/files/p8418n908.

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

MLA Handbook (7^th Edition):

Liu,Ming. “BEHAVIOR OF SHALE CAPROCK UNDER EXPOSURE TO SUPERCRITICAL CO2.” 2013. Web. 24 Jan 2021.

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

Vancouver:

Liu,Ming. BEHAVIOR OF SHALE CAPROCK UNDER EXPOSURE TO SUPERCRITICAL CO2. [Internet] [Masters thesis]. University of Alberta; 2013. [cited 2021 Jan 24]. Available from: https://era.library.ualberta.ca/files/p8418n908.

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

Council of Science Editors:

Liu,Ming. BEHAVIOR OF SHALE CAPROCK UNDER EXPOSURE TO SUPERCRITICAL CO2. [Masters Thesis]. University of Alberta; 2013. Available from: https://era.library.ualberta.ca/files/p8418n908

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

Texas A&M University

8. Czernia, Bartosz Tadeusz. Development of a Mechanistic Model for Capillary Pressures and Relative Permeabilities to Estimate Oil and Gas Recoveries for Unconventional Reservoirs Under Depletion and Gas Injection.

Degree: MS, Petroleum Engineering, 2018, Texas A&M University

URL: http://hdl.handle.net/1969.1/173744

► A mechanistic model was created to calculate recovery factors and capillary pressure curves for unconventional reservoirs. A key aspect of the model is that it… (more)

▼ A mechanistic model was created to calculate recovery factors and capillary pressure curves for unconventional reservoirs. A key aspect of the model is that it accounts for the effect of fluid confinement that occurs inside small diameter pores in unconventional reservoirs. Confinement effects are incorporated through the calculation of capillarity via the Young-Laplace equation. The model is intended to provide an estimate of recovery factors that is faster and simpler to use than a full reservoir simulation. The model simulates initial depletion of the reservoir and then simulates one or more gas injection steps as an enhanced oil recovery technique. The results from the model are unique to the specific reservoir fluid composition, pore size distribution, degree of depletion, injection gas composition, injection gas amount and number of injection steps specified for the run. The results from the model are compared against small-scale reservoir simulation runs under equivalent conditions. The simulator used for the comparison is a Matlab based, compositional research simulator that is capable of modeling pore confinement effects. For an idealized reservoir model, the mechanistic model and the reservoir simulation results match for both the initial depletion and gas injection portions of the run. For larger reservoir models containing a greater number of cells, the mechanistic model matches the simulation results closely for the initial depletion. However, the two methods do not match for the gas injection portion of the run. This mismatch occurs because the mechanistic model is not capable of modeling the complex mixing of the injection gas with the reservoir fluids as the gas moves through the reservoir volume. To isolate the impact of confinement on production, each reservoir simulation is run once with confinement effects considered and again using bulk fluid behavior (no confinement effects). All other run parameters are held constant between the runs. For a black oil reservoir fluid, the confinement effects increase the ratio of oil to gas production. For a volatile oil, confinement has a minimal impact on the ratio of oil to gas production. Advisors/Committee Members: Barrufet, Maria A (advisor), Blasingame, Thomas A (committee member), Lee, William J (committee member).

Subjects/Keywords: Unconventional; Recovery Factors; Depletion; Gas Injection; Capillary Pressure

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Czernia, B. T. (2018). Development of a Mechanistic Model for Capillary Pressures and Relative Permeabilities to Estimate Oil and Gas Recoveries for Unconventional Reservoirs Under Depletion and Gas Injection. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/173744

Chicago Manual of Style (16^th Edition):

Czernia, Bartosz Tadeusz. “Development of a Mechanistic Model for Capillary Pressures and Relative Permeabilities to Estimate Oil and Gas Recoveries for Unconventional Reservoirs Under Depletion and Gas Injection.” 2018. Masters Thesis, Texas A&M University. Accessed January 24, 2021. http://hdl.handle.net/1969.1/173744.

MLA Handbook (7^th Edition):

Czernia, Bartosz Tadeusz. “Development of a Mechanistic Model for Capillary Pressures and Relative Permeabilities to Estimate Oil and Gas Recoveries for Unconventional Reservoirs Under Depletion and Gas Injection.” 2018. Web. 24 Jan 2021.

Vancouver:

Czernia BT. Development of a Mechanistic Model for Capillary Pressures and Relative Permeabilities to Estimate Oil and Gas Recoveries for Unconventional Reservoirs Under Depletion and Gas Injection. [Internet] [Masters thesis]. Texas A&M University; 2018. [cited 2021 Jan 24]. Available from: http://hdl.handle.net/1969.1/173744.

Council of Science Editors:

Czernia BT. Development of a Mechanistic Model for Capillary Pressures and Relative Permeabilities to Estimate Oil and Gas Recoveries for Unconventional Reservoirs Under Depletion and Gas Injection. [Masters Thesis]. Texas A&M University; 2018. Available from: http://hdl.handle.net/1969.1/173744

Texas A&M University

9. Czernia, Bartosz Tadeusz. Development of a Mechanistic Model for Capillary Pressures and Relative Permeabilities to Estimate Oil and Gas Recoveries for Unconventional Reservoirs Under Depletion and Gas Injection.

Degree: MS, Petroleum Engineering, 2018, Texas A&M University

URL: http://hdl.handle.net/1969.1/173839

► A mechanistic model was created to calculate recovery factors and capillary pressure curves for unconventional reservoirs. A key aspect of the model is that it… (more)

▼ A mechanistic model was created to calculate recovery factors and capillary pressure curves for unconventional reservoirs. A key aspect of the model is that it accounts for the effect of fluid confinement that occurs inside small diameter pores in unconventional reservoirs. Confinement effects are incorporated through the calculation of capillarity via the Young-Laplace equation. The model is intended to provide an estimate of recovery factors that is faster and simpler to use than a full reservoir simulation. The model simulates initial depletion of the reservoir and then simulates one or more gas injection steps as an enhanced oil recovery technique. The results from the model are unique to the specific reservoir fluid composition, pore size distribution, degree of depletion, injection gas composition, injection gas amount and number of injection steps specified for the run. The results from the model are compared against small-scale reservoir simulation runs under equivalent conditions. The simulator used for the comparison is a Matlab based, compositional research simulator that is capable of modeling pore confinement effects. For an idealized reservoir model, the mechanistic model and the reservoir simulation results match for both the initial depletion and gas injection portions of the run. For larger reservoir models containing a greater number of cells, the mechanistic model matches the simulation results closely for the initial depletion. However, the two methods do not match for the gas injection portion of the run. This mismatch occurs because the mechanistic model is not capable of modeling the complex mixing of the injection gas with the reservoir fluids as the gas moves through the reservoir volume. To isolate the impact of confinement on production, each reservoir simulation is run once with confinement effects considered and again using bulk fluid behavior (no confinement effects). All other run parameters are held constant between the runs. For a black oil reservoir fluid, the confinement effects increase the ratio of oil to gas production. For a volatile oil, confinement has a minimal impact on the ratio of oil to gas production. Advisors/Committee Members: Barrufet, Maria A (advisor), Blasingame, Thomas A (committee member), Lee, William J (committee member).

Subjects/Keywords: Unconventional; Recovery Factors; Depletion; Gas Injection; Capillary Pressure

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Czernia, B. T. (2018). Development of a Mechanistic Model for Capillary Pressures and Relative Permeabilities to Estimate Oil and Gas Recoveries for Unconventional Reservoirs Under Depletion and Gas Injection. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/173839

Chicago Manual of Style (16^th Edition):

Czernia, Bartosz Tadeusz. “Development of a Mechanistic Model for Capillary Pressures and Relative Permeabilities to Estimate Oil and Gas Recoveries for Unconventional Reservoirs Under Depletion and Gas Injection.” 2018. Masters Thesis, Texas A&M University. Accessed January 24, 2021. http://hdl.handle.net/1969.1/173839.

MLA Handbook (7^th Edition):

Czernia, Bartosz Tadeusz. “Development of a Mechanistic Model for Capillary Pressures and Relative Permeabilities to Estimate Oil and Gas Recoveries for Unconventional Reservoirs Under Depletion and Gas Injection.” 2018. Web. 24 Jan 2021.

Vancouver:

Czernia BT. Development of a Mechanistic Model for Capillary Pressures and Relative Permeabilities to Estimate Oil and Gas Recoveries for Unconventional Reservoirs Under Depletion and Gas Injection. [Internet] [Masters thesis]. Texas A&M University; 2018. [cited 2021 Jan 24]. Available from: http://hdl.handle.net/1969.1/173839.

Council of Science Editors:

Czernia BT. Development of a Mechanistic Model for Capillary Pressures and Relative Permeabilities to Estimate Oil and Gas Recoveries for Unconventional Reservoirs Under Depletion and Gas Injection. [Masters Thesis]. Texas A&M University; 2018. Available from: http://hdl.handle.net/1969.1/173839

Texas A&M University

10. Wu, Tao. Permeability prediction and drainage capillary pressure simulation in sandstone reservoirs.

Degree: PhD, Geology, 2005, Texas A&M University

URL: http://hdl.handle.net/1969.1/1496

► Knowledge of reservoir porosity, permeability, and capillary pressure is essential to exploration and production of hydrocarbons. Although porosity can be interpreted fairly accurately from well… (more)

▼ Knowledge of reservoir porosity, permeability, and capillary pressure is essential to exploration and production of hydrocarbons. Although porosity can be interpreted fairly accurately from well logs, permeability and capillary pressure must be measured from core. Estimating permeability and capillary pressure from well logs would be valuable where cores are unavailable. This study is to correlate permeability with porosity to predict permeability and capillary pressures. Relationships between permeability to porosity can be complicated by diagenetic processes like compaction, cementation, dissolution, and occurrence of clay minerals. These diagenetic alterations can reduce total porosity, and more importantly, reduce effective porosity available for fluid flow. To better predict permeability, effective porosity needs to be estimated. A general equation is proposed to estimate effective porosity. Permeability is predicted from effective porosity by empirical and theoretical equations. A new capillary pressure model is proposed. It is based on previous study, and largely empirical. It is tested with over 200 samples covering a wide range of lithology (clean sandstone, shaly sandstone, and carbonates dominated by intergranular pores). Parameters in this model include: interfacial tension, contact angle, shape factor, porosity, permeability, irreducible water saturation, and displacement pressure. These parameters can be measured from routine core analysis, estimated from well log, and assumed. An empirical equation is proposed to calculate displacement pressure from porosity and permeability. The new capillary-pressure model is applied to evaluate sealing capacity of seals, calculate transition zone thickness and saturation above free water level in reservoirs. Good results are achieved through integration of well log data, production data, core, and geological concepts. Advisors/Committee Members: Berg, Robert R. (advisor), Ahr, Wayne (committee member), Blasingame, Thomas (committee member), Watkins, Joel (committee member), Willis, Brian (committee member).

Subjects/Keywords: Permeability; Capillary Pressure; Sandstone Reservoirs

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APA (6^th Edition):

Wu, T. (2005). Permeability prediction and drainage capillary pressure simulation in sandstone reservoirs. (Doctoral Dissertation). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/1496

Chicago Manual of Style (16^th Edition):

Wu, Tao. “Permeability prediction and drainage capillary pressure simulation in sandstone reservoirs.” 2005. Doctoral Dissertation, Texas A&M University. Accessed January 24, 2021. http://hdl.handle.net/1969.1/1496.

MLA Handbook (7^th Edition):

Wu, Tao. “Permeability prediction and drainage capillary pressure simulation in sandstone reservoirs.” 2005. Web. 24 Jan 2021.

Vancouver:

Wu T. Permeability prediction and drainage capillary pressure simulation in sandstone reservoirs. [Internet] [Doctoral dissertation]. Texas A&M University; 2005. [cited 2021 Jan 24]. Available from: http://hdl.handle.net/1969.1/1496.

Council of Science Editors:

Wu T. Permeability prediction and drainage capillary pressure simulation in sandstone reservoirs. [Doctoral Dissertation]. Texas A&M University; 2005. Available from: http://hdl.handle.net/1969.1/1496

Texas A&M University

11. Huet, Caroline Cecile. Semi-analytical estimates of permeability obtained from capillary pressure.

Degree: MS, Petroleum Engineering, 2006, Texas A&M University

URL: http://hdl.handle.net/1969.1/3042

► The objective of this research is to develop and test a new concept for predicting permeability from routine rock properties. First, we develop a model… (more)

Subjects/Keywords: Permeability; Capillary pressure; petrophysics

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APA (6^th Edition):

Huet, C. C. (2006). Semi-analytical estimates of permeability obtained from capillary pressure. (Masters Thesis). Texas A&M University. Retrieved from http://hdl.handle.net/1969.1/3042

Chicago Manual of Style (16^th Edition):

Huet, Caroline Cecile. “Semi-analytical estimates of permeability obtained from capillary pressure.” 2006. Masters Thesis, Texas A&M University. Accessed January 24, 2021. http://hdl.handle.net/1969.1/3042.

MLA Handbook (7^th Edition):

Huet, Caroline Cecile. “Semi-analytical estimates of permeability obtained from capillary pressure.” 2006. Web. 24 Jan 2021.

Vancouver:

Huet CC. Semi-analytical estimates of permeability obtained from capillary pressure. [Internet] [Masters thesis]. Texas A&M University; 2006. [cited 2021 Jan 24]. Available from: http://hdl.handle.net/1969.1/3042.

Council of Science Editors:

Huet CC. Semi-analytical estimates of permeability obtained from capillary pressure. [Masters Thesis]. Texas A&M University; 2006. Available from: http://hdl.handle.net/1969.1/3042

Penn State University

12. Nojabaei, Bahareh. Phase Behavior And Flow Analysis Of Shale Reservoirs Using A Compositionally-extended Black-oil Approach.

Degree: 2015, Penn State University

URL: https://submit-etda.libraries.psu.edu/catalog/27487

► Pore sizes are on the order of nanometers for shale and tight rock formations. Such small pores can affect the phase behavior of in-situ oil… (more)

▼ Pore sizes are on the order of nanometers for shale and tight rock formations. Such small pores can affect the phase behavior of in-situ oil and gas owing to increased capillary pressure. Not accounting for increased capillary pressure can lead to inaccurate estimates of ultimate recovery. In this research, capillary pressure is coupled with phase equilibrium equations and the resulting system of nonlinear fugacity equations is solved to present a comprehensive examination of the effect of small pores on saturation pressures and fluid properties. The results show, for the first time, that accounting for the impact of small pore throats on PVT properties explains the inconsistent GOR behavior observed in tight formations. The small pores decrease bubble-point pressures and either decrease or increase dew-point pressures depending on which part of the two-phase envelope is examined. To estimate production from shale reservoirs, a simulation model should be designed to account for the effect of high capillary pressure on fluid properties. We have chosen to use a compositionally-extended black-oil approach since it is faster and more robust compared to a fully compositional simulation model. Black-oil fluid properties are calculated by flash calculations of the reservoir fluid. Allowing for a variable bubble-point pressure in black- or volatile-oil models requires a table of fluid properties be extended above the original bubble-point. We calculate continuous black-oil fluid properties above the original bubble-point by adding a fraction of the equilibrium gas at one bubble-point pressure to achieve a larger bubble-point pressure. This procedure continues until a critical point is reached. Unlike other commonly used methods, our approach provides a smooth and continuous pressure-composition curve to the critical point. If another component is added, the model further allows for injection of methane or CO2 to increase oil recovery. Further, the approach allows the use of black-oil or volatile-oil properties for tight rocks where capillary pressure affects hydrocarbon phase behavior. The compositional equations (gas, oil, and water components) are solved directly with principle unknowns of oil pressure, overall gas composition, and water saturation. Flash calculations in the model are non-iterative and are based on K-values calculated explicitly from the black-oil data. The advantage of solving the black-oil model using the compositional equations is to increase robustness of the simulations owing to a variable bubble-point pressure that is a function of two parameters, namely gas content and capillary pressure. Leverett J-functions are used to establish the effective pore size-Pc-saturation relationship. The input fluid data to the simulator are pre-calculated fluid properties as functions of pressure for three fixed pore sizes. During the simulation, at any pressure and saturation, fluid properties are calculated at the effective pore radius by using linear interpolation between these three data sets. Our results… Advisors/Committee Members: Russell Taylor Johns, Dissertation Advisor/Co-Advisor, Russell Taylor Johns, Committee Chair/Co-Chair, Turgay Ertekin, Committee Member, Luis Ayala, Committee Member, James Terry Engelder, Special Member.

Subjects/Keywords: Shale reservoirs; phase behavior; reservoir flow simulation; capillary pressure

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APA (6^th Edition):

Nojabaei, B. (2015). Phase Behavior And Flow Analysis Of Shale Reservoirs Using A Compositionally-extended Black-oil Approach. (Thesis). Penn State University. Retrieved from https://submit-etda.libraries.psu.edu/catalog/27487

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Nojabaei, Bahareh. “Phase Behavior And Flow Analysis Of Shale Reservoirs Using A Compositionally-extended Black-oil Approach.” 2015. Thesis, Penn State University. Accessed January 24, 2021. https://submit-etda.libraries.psu.edu/catalog/27487.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Nojabaei, Bahareh. “Phase Behavior And Flow Analysis Of Shale Reservoirs Using A Compositionally-extended Black-oil Approach.” 2015. Web. 24 Jan 2021.

Vancouver:

Nojabaei B. Phase Behavior And Flow Analysis Of Shale Reservoirs Using A Compositionally-extended Black-oil Approach. [Internet] [Thesis]. Penn State University; 2015. [cited 2021 Jan 24]. Available from: https://submit-etda.libraries.psu.edu/catalog/27487.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Nojabaei B. Phase Behavior And Flow Analysis Of Shale Reservoirs Using A Compositionally-extended Black-oil Approach. [Thesis]. Penn State University; 2015. Available from: https://submit-etda.libraries.psu.edu/catalog/27487

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

University of Manchester

13. Al-Defai, Nidhal. The consequences of the dewatering of freshly-mixed wet mortars by the capillary suction of brick masonry.

Degree: PhD, 2013, University of Manchester

URL: https://www.research.manchester.ac.uk/portal/en/theses/the-consequences-of-the-dewatering-of-freshlymixed-wet-mortars-by-the-capillary-suction-of-brick-masonry(01374525-5432-445a-a6b3-7833a5fb994d).html ; http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.607408

► The main water transport properties of clay brick are critically examined in respect of suction and water content. An experimental investigation is carried out to… (more)

Subjects/Keywords: 624.1; Dewatering, freshly-mixed mortar, brick masonry, capillary pressure, cement, lime

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APA (6^th Edition):

Al-Defai, N. (2013). The consequences of the dewatering of freshly-mixed wet mortars by the capillary suction of brick masonry. (Doctoral Dissertation). University of Manchester. Retrieved from https://www.research.manchester.ac.uk/portal/en/theses/the-consequences-of-the-dewatering-of-freshlymixed-wet-mortars-by-the-capillary-suction-of-brick-masonry(01374525-5432-445a-a6b3-7833a5fb994d).html ; http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.607408

Chicago Manual of Style (16^th Edition):

Al-Defai, Nidhal. “The consequences of the dewatering of freshly-mixed wet mortars by the capillary suction of brick masonry.” 2013. Doctoral Dissertation, University of Manchester. Accessed January 24, 2021. https://www.research.manchester.ac.uk/portal/en/theses/the-consequences-of-the-dewatering-of-freshlymixed-wet-mortars-by-the-capillary-suction-of-brick-masonry(01374525-5432-445a-a6b3-7833a5fb994d).html ; http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.607408.

MLA Handbook (7^th Edition):

Al-Defai, Nidhal. “The consequences of the dewatering of freshly-mixed wet mortars by the capillary suction of brick masonry.” 2013. Web. 24 Jan 2021.

Vancouver:

Al-Defai N. The consequences of the dewatering of freshly-mixed wet mortars by the capillary suction of brick masonry. [Internet] [Doctoral dissertation]. University of Manchester; 2013. [cited 2021 Jan 24]. Available from: https://www.research.manchester.ac.uk/portal/en/theses/the-consequences-of-the-dewatering-of-freshlymixed-wet-mortars-by-the-capillary-suction-of-brick-masonry(01374525-5432-445a-a6b3-7833a5fb994d).html ; http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.607408.

Council of Science Editors:

Al-Defai N. The consequences of the dewatering of freshly-mixed wet mortars by the capillary suction of brick masonry. [Doctoral Dissertation]. University of Manchester; 2013. Available from: https://www.research.manchester.ac.uk/portal/en/theses/the-consequences-of-the-dewatering-of-freshlymixed-wet-mortars-by-the-capillary-suction-of-brick-masonry(01374525-5432-445a-a6b3-7833a5fb994d).html ; http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.607408

14. Parker, Paul E. Capillary Permeability to Macromolecules at Normal and Hypobaric Pressure.

Degree: 1969, North Texas State University

URL: https://digital.library.unt.edu/ark:/67531/metadc131162/

► The purpose of this investigation was to study the effects of decreased barometric pressure on the transcapillary movement of molecules by monitoring the macromolecular capillary… (more)

Subjects/Keywords: capillary; macromolecules; pressure; lymph; biology

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APA (6^th Edition):

Parker, P. E. (1969). Capillary Permeability to Macromolecules at Normal and Hypobaric Pressure. (Thesis). North Texas State University. Retrieved from https://digital.library.unt.edu/ark:/67531/metadc131162/

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Parker, Paul E. “Capillary Permeability to Macromolecules at Normal and Hypobaric Pressure.” 1969. Thesis, North Texas State University. Accessed January 24, 2021. https://digital.library.unt.edu/ark:/67531/metadc131162/.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Parker, Paul E. “Capillary Permeability to Macromolecules at Normal and Hypobaric Pressure.” 1969. Web. 24 Jan 2021.

Vancouver:

Parker PE. Capillary Permeability to Macromolecules at Normal and Hypobaric Pressure. [Internet] [Thesis]. North Texas State University; 1969. [cited 2021 Jan 24]. Available from: https://digital.library.unt.edu/ark:/67531/metadc131162/.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Parker PE. Capillary Permeability to Macromolecules at Normal and Hypobaric Pressure. [Thesis]. North Texas State University; 1969. Available from: https://digital.library.unt.edu/ark:/67531/metadc131162/

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Louisiana State University

15. Jafari, Mohammad. Pore-Scale and Conventional Wettability Measurement Considerations for Improving Certainty of Geological CO2 Sequestration.

Degree: PhD, Civil and Environmental Engineering, 2018, Louisiana State University

URL: https://digitalcommons.lsu.edu/gradschool_dissertations/4628

► Parallel to the approach of developing zero-carbon-emission energies, other solutions have been recently proposed to decrease the amount of CO2 emissions into the atmosphere.… (more)

▼ Parallel to the approach of developing zero-carbon-emission energies, other solutions have been recently proposed to decrease the amount of CO2 emissions into the atmosphere. Geological CO2 sequestration (GCS) has provided economic benefits and slight adverse environmental effects. GCS involves capturing CO2 from large producers, then injecting it into deep layers of the earth’s subsurface to be stored for hundreds to thousands of years. A safe and economic GCS requires a profound knowledge of immiscible CO2-water/brine fluid flow in CO2 storage sites including capillary pressure which has a barrier effect against leakage. The main uncertainty in measuring capillary pressure is due to the wettability, which is quantified by contact angle of water/brine interface on rock surface. The objective of this study is to explore the reasons of uncertainty observed in conventional contact angle measurement and introduce a more realistic pore level contact angle measurement. The contact angle of water/brine on select minerals found in common rocks (silica and mica) was measured using a high-pressure, high-temperature chamber developed for a captive bubble test method. As an innovative method, pore-scale static and dynamic contact angles were also measured inside a high-pressure micromodel using a microscope. The results showed that the heterogeneity on minerals surface plays an important role in controlling contact angle variation with time. With unsaturated fluid (water/brine-CO2) condition, which is more realistic in the short-term after CO2 injection, the contact angle can increase due to a pinned triple line (the line on which the three phases of the liquid, gaseous, and solid surface meet) as a result of heterogeneity. An increased contact angle causes the capillary pressure to decrease resulting in a higher leakage risk. The micro-scale dynamic contact angle results showed that rocks were not as water-wet as assumed in literature when conventional measurement methods on flat surfaces of minerals were used. An increase of pressure and salinity changed the glass (silica) behavior from water-wet to intermediate-wet. Pore-scale contact angle measurement provides more realistic wettability behavior of geo-materials and increases the certainty the simulations used for assessing safety and efficiency of storage sites.

Subjects/Keywords: Geologic Carbon sequestration; Wettability; Contact angle; Pore-Scale; Capillary Pressure; Micromodel

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APA (6^th Edition):

Jafari, M. (2018). Pore-Scale and Conventional Wettability Measurement Considerations for Improving Certainty of Geological CO2 Sequestration. (Doctoral Dissertation). Louisiana State University. Retrieved from https://digitalcommons.lsu.edu/gradschool_dissertations/4628

Chicago Manual of Style (16^th Edition):

Jafari, Mohammad. “Pore-Scale and Conventional Wettability Measurement Considerations for Improving Certainty of Geological CO2 Sequestration.” 2018. Doctoral Dissertation, Louisiana State University. Accessed January 24, 2021. https://digitalcommons.lsu.edu/gradschool_dissertations/4628.

MLA Handbook (7^th Edition):

Jafari, Mohammad. “Pore-Scale and Conventional Wettability Measurement Considerations for Improving Certainty of Geological CO2 Sequestration.” 2018. Web. 24 Jan 2021.

Vancouver:

Jafari M. Pore-Scale and Conventional Wettability Measurement Considerations for Improving Certainty of Geological CO2 Sequestration. [Internet] [Doctoral dissertation]. Louisiana State University; 2018. [cited 2021 Jan 24]. Available from: https://digitalcommons.lsu.edu/gradschool_dissertations/4628.

Council of Science Editors:

Jafari M. Pore-Scale and Conventional Wettability Measurement Considerations for Improving Certainty of Geological CO2 Sequestration. [Doctoral Dissertation]. Louisiana State University; 2018. Available from: https://digitalcommons.lsu.edu/gradschool_dissertations/4628

Virginia Tech

16. Wu, Hao. Numerical Investigations of Geologic CO2 Sequestration Using Physics-Based and Machine Learning Modeling Strategies.

Degree: PhD, Geosciences, 2020, Virginia Tech

URL: http://hdl.handle.net/10919/99604

► Carbon capture and sequestration (CCS) has been proposed as a technological approach to mitigate the deleterious effects of anthropogenic CO2 emissions. During CCS, CO2 is… (more)

Subjects/Keywords: CO2 sequestration; capillary pressure; relative permeability; reactive transport; machine learning

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APA (6^th Edition):

Wu, H. (2020). Numerical Investigations of Geologic CO2 Sequestration Using Physics-Based and Machine Learning Modeling Strategies. (Doctoral Dissertation). Virginia Tech. Retrieved from http://hdl.handle.net/10919/99604

Chicago Manual of Style (16^th Edition):

Wu, Hao. “Numerical Investigations of Geologic CO2 Sequestration Using Physics-Based and Machine Learning Modeling Strategies.” 2020. Doctoral Dissertation, Virginia Tech. Accessed January 24, 2021. http://hdl.handle.net/10919/99604.

MLA Handbook (7^th Edition):

Wu, Hao. “Numerical Investigations of Geologic CO2 Sequestration Using Physics-Based and Machine Learning Modeling Strategies.” 2020. Web. 24 Jan 2021.

Vancouver:

Wu H. Numerical Investigations of Geologic CO2 Sequestration Using Physics-Based and Machine Learning Modeling Strategies. [Internet] [Doctoral dissertation]. Virginia Tech; 2020. [cited 2021 Jan 24]. Available from: http://hdl.handle.net/10919/99604.

Council of Science Editors:

Wu H. Numerical Investigations of Geologic CO2 Sequestration Using Physics-Based and Machine Learning Modeling Strategies. [Doctoral Dissertation]. Virginia Tech; 2020. Available from: http://hdl.handle.net/10919/99604

University of New South Wales

17. Shikhov, Igor. Integration of micro-CT and NMR-based techniques for reservoir rock characterization.

Degree: Petroleum Engineering, 2015, University of New South Wales

URL: http://handle.unsw.edu.au/1959.4/55768 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:39169/SOURCE02?view=true

► The petrophysical interpretation of 2D diffusion-relaxation NMR responses isa long-standing problem complicated by the complexity of sedimentary rocks as wellas the properties of saturating fluids… (more)

▼ The petrophysical interpretation of 2D diffusion-relaxation NMR responses isa long-standing problem complicated by the complexity of sedimentary rocks as wellas the properties of saturating fluids including crude oils and the ill-posedness of theunderlying mathematical problem. We aim to improve the quality of petrophysicalproperties estimates, such as permeability, capillary pressure and relative permeability curves and fluid typing with the aid of NMR techniques using a combinationof numerically simulated low-field NMR and μ-CT imaging techniques.In first instance we study in detail the NMR responses of complex fluids andthe influence of environmental factors like oxygen saturation. A simulation strategyfor the fluids themselves using a multi-component fluid consisting of independentcomponents is developed.The distribution of fluids in sedimentary rocks depends on capillary pressurehistory. We simulate primary drainage on μ-CT digitized rock representations usingmorphological transformations. The approach is used for different potential functions to implement common capillary pressure techniques (porous plate, mercuryporosimetry (MICP) and centrifuge multi-speed). We evaluate the influence of specific boundary conditions, the effect of image resolution, and compare to saturationprofiles measured by NMR methods. We show good agreement for three sandstonerocks.Spatially-resolved NMR is used to estimate two-phase air-brine relative permeability. Using a simulated centrifuge (primary) drainage to set a gradient of partial saturations,a set of longitudinal relaxation time distributions is obtained on linearly-spaced subsets each emulating a volumetric point of MRI experiment. SimulatedNMR-based relative permeability curves show reasonable agreement with experimentand to standard steady- and unsteady-state special core analysis (SCAL)techniques.Quantitative interpretation of NMR response from rocks containing crude iscomplicated. We model the NMR response of crude oil as a weighted mixture ofdistinctive components. Environmental effects like oxygen paramagnetic relaxationenhancement are corrected using experimentally established correlation to a carbonnumber. We show agreement between experiment and simulation for two sandstonerocks for fully and partially saturated systems, potentially paving the way for extendingNMR-based relaxivity permeability techniques to samples saturated withcrude. Advisors/Committee Members: Arns, Christoph, Petroleum Engineering, Faculty of Engineering, UNSW.

Subjects/Keywords: capillary pressure; low-field NMR; micro-CT; relative permeability; petroleum fluids

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APA (6^th Edition):

Shikhov, I. (2015). Integration of micro-CT and NMR-based techniques for reservoir rock characterization. (Doctoral Dissertation). University of New South Wales. Retrieved from http://handle.unsw.edu.au/1959.4/55768 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:39169/SOURCE02?view=true

Chicago Manual of Style (16^th Edition):

Shikhov, Igor. “Integration of micro-CT and NMR-based techniques for reservoir rock characterization.” 2015. Doctoral Dissertation, University of New South Wales. Accessed January 24, 2021. http://handle.unsw.edu.au/1959.4/55768 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:39169/SOURCE02?view=true.

MLA Handbook (7^th Edition):

Shikhov, Igor. “Integration of micro-CT and NMR-based techniques for reservoir rock characterization.” 2015. Web. 24 Jan 2021.

Vancouver:

Shikhov I. Integration of micro-CT and NMR-based techniques for reservoir rock characterization. [Internet] [Doctoral dissertation]. University of New South Wales; 2015. [cited 2021 Jan 24]. Available from: http://handle.unsw.edu.au/1959.4/55768 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:39169/SOURCE02?view=true.

Council of Science Editors:

Shikhov I. Integration of micro-CT and NMR-based techniques for reservoir rock characterization. [Doctoral Dissertation]. University of New South Wales; 2015. Available from: http://handle.unsw.edu.au/1959.4/55768 ; https://unsworks.unsw.edu.au/fapi/datastream/unsworks:39169/SOURCE02?view=true

University of Texas – Austin

18. 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

URL: http://hdl.handle.net/2152/46515

► 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 (6^th 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 (16^th 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 January 24, 2021. http://hdl.handle.net/2152/46515.

MLA Handbook (7^th 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. 24 Jan 2021.

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 2021 Jan 24]. 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

19. Yokoyama, Yoshio. The Effects of Capillary Pressure on Displacements in Stratified Porous Media.

Degree: Masters of Science in Engineering, Petroleum Engineering, 1980, University of Texas – Austin

URL: http://dx.doi.org/10.26153/tsw/7559

► The purpose of this study is to obtain a better understanding of capillary pressure effects on fluid dis-placement in stratified porous media. We do this… (more)

Subjects/Keywords: Capillary pressure; Porous media

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APA (6^th Edition):

Yokoyama, Y. (1980). The Effects of Capillary Pressure on Displacements in Stratified Porous Media. (Masters Thesis). University of Texas – Austin. Retrieved from http://dx.doi.org/10.26153/tsw/7559

Chicago Manual of Style (16^th Edition):

Yokoyama, Yoshio. “The Effects of Capillary Pressure on Displacements in Stratified Porous Media.” 1980. Masters Thesis, University of Texas – Austin. Accessed January 24, 2021. http://dx.doi.org/10.26153/tsw/7559.

MLA Handbook (7^th Edition):

Yokoyama, Yoshio. “The Effects of Capillary Pressure on Displacements in Stratified Porous Media.” 1980. Web. 24 Jan 2021.

Vancouver:

Yokoyama Y. The Effects of Capillary Pressure on Displacements in Stratified Porous Media. [Internet] [Masters thesis]. University of Texas – Austin; 1980. [cited 2021 Jan 24]. Available from: http://dx.doi.org/10.26153/tsw/7559.

Council of Science Editors:

Yokoyama Y. The Effects of Capillary Pressure on Displacements in Stratified Porous Media. [Masters Thesis]. University of Texas – Austin; 1980. Available from: http://dx.doi.org/10.26153/tsw/7559

University of Texas – Austin

20. Akhbari, Daria. Under-pressure in the Bravo Dome natural CO₂ field and its implications for geological CO₂ storage (GCS).

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

URL: http://hdl.handle.net/2152/68751

► Geological carbon storage (GCS) has the potential to reduce anthropogenic CO₂ emissions, if large volumes can be injected. Storage capacity is limited by regional pressure… (more)

Subjects/Keywords: CO2; CO₂; Under-pressure condition; Capillary pressure; Abnormal pressure; Geological CO2 storage; Geological CO₂ storage; Reservoir compartmentalization; Convective dissolution

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APA (6^th Edition):

Akhbari, D. (2018). Under-pressure in the Bravo Dome natural CO₂ field and its implications for geological CO₂ storage (GCS). (Doctoral Dissertation). University of Texas – Austin. Retrieved from http://hdl.handle.net/2152/68751

Chicago Manual of Style (16^th Edition):

Akhbari, Daria. “Under-pressure in the Bravo Dome natural CO₂ field and its implications for geological CO₂ storage (GCS).” 2018. Doctoral Dissertation, University of Texas – Austin. Accessed January 24, 2021. http://hdl.handle.net/2152/68751.

MLA Handbook (7^th Edition):

Akhbari, Daria. “Under-pressure in the Bravo Dome natural CO₂ field and its implications for geological CO₂ storage (GCS).” 2018. Web. 24 Jan 2021.

Vancouver:

Akhbari D. Under-pressure in the Bravo Dome natural CO₂ field and its implications for geological CO₂ storage (GCS). [Internet] [Doctoral dissertation]. University of Texas – Austin; 2018. [cited 2021 Jan 24]. Available from: http://hdl.handle.net/2152/68751.

Council of Science Editors:

Akhbari D. Under-pressure in the Bravo Dome natural CO₂ field and its implications for geological CO₂ storage (GCS). [Doctoral Dissertation]. University of Texas – Austin; 2018. Available from: http://hdl.handle.net/2152/68751

University of Texas – Austin

21. -6050-5391. Capillary pressure curve and liquid permeability estimation in tight oil reservoirs using pressure decline versus time data.

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

URL: http://dx.doi.org/10.26153/tsw/2173

► Estimating oil recovery from shale is a difficult process because organic mudrocks have very low permeability (10nD - 100nD), high kerogen and clay content, a… (more)

Subjects/Keywords: Capillary pressure; Liquid permeability; Tight oil reservoirs; Pressure decline; Time data; Shale oil recovery; Tight rocks; Capillary drainage curve; Eagle Ford shale; Relative permeability; Fluid saturation estimation; Fluid distributions

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APA (6^th Edition):

-6050-5391. (2018). Capillary pressure curve and liquid permeability estimation in tight oil reservoirs using pressure decline versus time data. (Masters Thesis). University of Texas – Austin. Retrieved from http://dx.doi.org/10.26153/tsw/2173

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

Chicago Manual of Style (16^th Edition):

-6050-5391. “Capillary pressure curve and liquid permeability estimation in tight oil reservoirs using pressure decline versus time data.” 2018. Masters Thesis, University of Texas – Austin. Accessed January 24, 2021. http://dx.doi.org/10.26153/tsw/2173.

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

MLA Handbook (7^th Edition):

-6050-5391. “Capillary pressure curve and liquid permeability estimation in tight oil reservoirs using pressure decline versus time data.” 2018. Web. 24 Jan 2021.

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

Vancouver:

-6050-5391. Capillary pressure curve and liquid permeability estimation in tight oil reservoirs using pressure decline versus time data. [Internet] [Masters thesis]. University of Texas – Austin; 2018. [cited 2021 Jan 24]. Available from: http://dx.doi.org/10.26153/tsw/2173.

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

Council of Science Editors:

-6050-5391. Capillary pressure curve and liquid permeability estimation in tight oil reservoirs using pressure decline versus time data. [Masters Thesis]. University of Texas – Austin; 2018. Available from: http://dx.doi.org/10.26153/tsw/2173

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

University of California – Berkeley

22. Gunterman, Haluna Penelope Frances. Characterization of Fuel-Cell Diffusion Media.

Degree: Chemical Engineering, 2011, University of California – Berkeley

URL: http://www.escholarship.org/uc/item/2hd8f4wp

► Achieving proper water management in proton-exchange-membrane fuel cells (PEMFC) is an ongoing challenge. Current quantitative treatments of two-phase flow in fuel-cell diffusion media (DM) often… (more)

▼ Achieving proper water management in proton-exchange-membrane fuel cells (PEMFC) is an ongoing challenge. Current quantitative treatments of two-phase flow in fuel-cell diffusion media (DM) often assume saturation-dependent transport relations. However, these relations are not validated for the complex physical and chemical structure of the DM, and therefore lack predictive capabilities. Characterization of DM and their water-uptake profiles enables a fundamental understanding of the driving forces behind flooding and facilitates targeted improvement in the form of physically representative simulations. The objective of this work is to characterize, analyze, and explain the wettability and water-uptake behavior of fuel-cell components, namely the DM and catalyst layer (CL), based on manufacturing parameters and physiochemical structure, e.g., fiber structure and hydrophobic treatment of the DM, and chemical composition and crack formation of the CL. A combination of capillary-pressure saturation (PC-S) measurements, visual-imaging, and physical-characterization techniques is used to quantify water-uptake behavior and identify causal factors. On an intuitive level, Pc-S curves show the propensity of a material to uptake or eject water. The PC-S curves demonstrate that DM are neutrally wetting materials that neither spontaneously imbibe nor eject water. DM from various manufacturers exhibit signature features that can be explained partially by visual differences in fiber structure and deposition of a hydrophobic agent, polytetrafluoroethylene (PTFE). Although the initial addition of PTFE improves hydrophobicity of the sample, increasing PTFE loading does not show significant improvements and instead, as evidenced by pore-size-distribution (PSD) measurements, decreases porosity. Systematic studies of the PSDs demonstrate the level of variation that exists within DM and between DM produced by different manufacturers. To date, there have not been data on the wettability and water-uptake behavior of CLs. Isolated CLs were made in-house and commercially and tested for their PC-S response. CLs have the propensity to be highly hydrophilic and require capillary pressures as low as -80 kPa to eject water. The presence of Pt or surface cracks increases hydrophilicity. These findings suggest that saturation in CLs, especially cracked CLs, may exacerbate poor transport. Lastly, this work includes early-stage development of a limiting-current measurement that can be used to calculate effective transport properties as a function of saturation. Results indicate that the method is valid, and different DM have higher transport depending on the operating condition. The technique is yet in a formative stage, and this work includes advice and recommendations for operation and design improvements.

Subjects/Keywords: Energy; Capillary-pressure; Diffusion media; Effective diffusion; Fuel cell; Gas-diffusion layer; Water management

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APA (6^th Edition):

Gunterman, H. P. F. (2011). Characterization of Fuel-Cell Diffusion Media. (Thesis). University of California – Berkeley. Retrieved from http://www.escholarship.org/uc/item/2hd8f4wp

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Gunterman, Haluna Penelope Frances. “Characterization of Fuel-Cell Diffusion Media.” 2011. Thesis, University of California – Berkeley. Accessed January 24, 2021. http://www.escholarship.org/uc/item/2hd8f4wp.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Gunterman, Haluna Penelope Frances. “Characterization of Fuel-Cell Diffusion Media.” 2011. Web. 24 Jan 2021.

Vancouver:

Gunterman HPF. Characterization of Fuel-Cell Diffusion Media. [Internet] [Thesis]. University of California – Berkeley; 2011. [cited 2021 Jan 24]. Available from: http://www.escholarship.org/uc/item/2hd8f4wp.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Gunterman HPF. Characterization of Fuel-Cell Diffusion Media. [Thesis]. University of California – Berkeley; 2011. Available from: http://www.escholarship.org/uc/item/2hd8f4wp

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Penn State University

23. Zhang, Zhenzihao. Predicting Petrophysical Properties From Rate-Transient Data: An Artificial Intelligence Application.

Degree: 2017, Penn State University

URL: https://submit-etda.libraries.psu.edu/catalog/13985zuz112

► Traditional methods to obtaining relative permeability curves and capillary pressure curves were expensive and time consuming. The methods rely on cores which are typically retrieved… (more)

▼ Traditional methods to obtaining relative permeability curves and capillary pressure curves were expensive and time consuming. The methods rely on cores which are typically retrieved only for a small fraction of wells. This study proposes a new methodology for predicting petrophysical properties from rate-transient data. In this study, we develop artificial-intelligence-based tools that predict characteristics of three-phase relative permeability, characteristics of capillary pressure for water-oil system and liquid-gas system and formation permeability using rate-transient data. Petrophysical properties are related to rate-transient data since these properties govern the fluid flow dynamics in reservoirs. An artificial neural network (ANN) can mimic any functional relationship with a finite amount of discontinuities. This study develops ANNs for predicting petrophysical properties for four different kinds of reservoirs-a circular black-oil reservoir, a rectangular black-oil flow unit, a circular volatile-oil reservoir, and a circular naturally fractured black-oil reservoir. The well setting for the black-oil rectangular flow unit is horizontal well while those for the other three types of reservoir are vertical wells. In a very rapid manner, the developed ANNs infer characteristics of relative permeability for three phases, characteristics of capillary pressure curves for water-oil system and liquid-gas system, horizontal permeability and vertical permeability. With the predicted characteristics, relative permeability and capillary pressure data can be generated. The generated data as well as the predicted permeabilities can be applied in history matching and reservoir modeling. This ANN tool can be used along with production practices to improve our ability in reservoir description. This tool can fill in the spot for predicting petrophysical properties for uncored wells and provide reference for modeling drainage area including the wells. Advisors/Committee Members: Turgay Ertekin, Dissertation Advisor/Co-Advisor, Turgay Ertekin, Committee Chair/Co-Chair, John Yilin Wang, Committee Member, Hamid Emami-Meybodi, Committee Member, Ming Xiao, Outside Member.

Subjects/Keywords: Relative Permeability; Capillary Pressure; Permeability; Artificial Neural Network; Rate-Transient Data; Petrophysical Properties

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APA (6^th Edition):

Zhang, Z. (2017). Predicting Petrophysical Properties From Rate-Transient Data: An Artificial Intelligence Application. (Thesis). Penn State University. Retrieved from https://submit-etda.libraries.psu.edu/catalog/13985zuz112

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Zhang, Zhenzihao. “Predicting Petrophysical Properties From Rate-Transient Data: An Artificial Intelligence Application.” 2017. Thesis, Penn State University. Accessed January 24, 2021. https://submit-etda.libraries.psu.edu/catalog/13985zuz112.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Zhang, Zhenzihao. “Predicting Petrophysical Properties From Rate-Transient Data: An Artificial Intelligence Application.” 2017. Web. 24 Jan 2021.

Vancouver:

Zhang Z. Predicting Petrophysical Properties From Rate-Transient Data: An Artificial Intelligence Application. [Internet] [Thesis]. Penn State University; 2017. [cited 2021 Jan 24]. Available from: https://submit-etda.libraries.psu.edu/catalog/13985zuz112.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Zhang Z. Predicting Petrophysical Properties From Rate-Transient Data: An Artificial Intelligence Application. [Thesis]. Penn State University; 2017. Available from: https://submit-etda.libraries.psu.edu/catalog/13985zuz112

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

University of Waterloo

24. Zamel, Nada. Transfer of Mass and Heat in the Cathode of Polymer Electrolyte Membrane Fuel Cell.

Degree: 2007, University of Waterloo

URL: http://hdl.handle.net/10012/3139

► The need for alternative sources of energy with low to zero emissions has led to the development of polymer electrolyte membrane fuel cells. PEM fuel… (more)

▼ The need for alternative sources of energy with low to zero emissions has led to the development of polymer electrolyte membrane fuel cells. PEM fuel cells are electro-chemical devices that convert chemical energy to electricity by using hydrogen as the fuel and oxygen as the oxidant with water as the byproduct of this reaction. One of the major barriers to the commercialization of these cells is the losses that occur at the cathode due to the slow oxygen diffusion and sluggish electrochemical reaction, which are further amplified by the presence of liquid water. Numerous numerical and mathematical models are found in the literature, which investigate the transport phenomena in the cathode and their effects on the cell performance. In this thesis, the discussion of a two-dimensional, steady state, half cell model is put forward. The conservation equations for mass, momentum, species charge and energy are solved using the commercial software COMSOL Multiphysics. The conservation equations are applied to the cathode bipolar plate, gas diffusion layer and catalyst layer. The flow of gaseous species are assumed to be uniform in the channel. The catalyst layer is assumed to be composed of a uniform distribution of catalyst, liquid water, electrolyte, and void space. The Stefan-Maxwell equation is used to model the multi-species diffusion in the gas diffusion and catalyst layers. Due to the low relative species' velocity, the Darcy law is used to describe the transport of gas and liquid phases in the gas diffusion and catalyst layers. A serpentine flow field is used to distribute the oxidant over the active cathode electrode surface, with pressure loss in the flow direction along the channel. A sensitivity analysis is carried out to investigate the effects of pressure drop in the channel, permeability, inlet relative humidity and shoulder/channel ratio on the performance of the cell. Electron transport is shown to play an important role in determining the overall performance of the cathode. With a serpentine flow field, the oxygen consumption occurs more aggressively at the areas under the land since electrons are readily available at these areas. In addition, the reaction increases along the catalyst layer thickness and occurs more rapidly at the catalyst layer/membrane interface. The losses due to electron transport are much higher than those due to the proton transport. The sensitivity analysis put forward illustrated that with the increase of pressure drop along the channel flow field, the performance of the cell and liquid water removal are enhanced. Similarly, an increase in permeability of the porous material results in an increase in liquid water removal and cell performance. Further, the investigation of the inlet relative humidity effects revealed that the electrolyte conductivity has a significant effect on the performance up to a point. On a similar fashion, a decrease in shoulder/channel width ratio leads to an increase in performance and an increase in the leakage between neighboring channels. Finally, the…

Subjects/Keywords: Liquid water; Capillary pressure; Cross flow

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Zamel, N. (2007). Transfer of Mass and Heat in the Cathode of Polymer Electrolyte Membrane Fuel Cell. (Thesis). University of Waterloo. Retrieved from http://hdl.handle.net/10012/3139

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Zamel, Nada. “Transfer of Mass and Heat in the Cathode of Polymer Electrolyte Membrane Fuel Cell.” 2007. Thesis, University of Waterloo. Accessed January 24, 2021. http://hdl.handle.net/10012/3139.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Zamel, Nada. “Transfer of Mass and Heat in the Cathode of Polymer Electrolyte Membrane Fuel Cell.” 2007. Web. 24 Jan 2021.

Vancouver:

Zamel N. Transfer of Mass and Heat in the Cathode of Polymer Electrolyte Membrane Fuel Cell. [Internet] [Thesis]. University of Waterloo; 2007. [cited 2021 Jan 24]. Available from: http://hdl.handle.net/10012/3139.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Zamel N. Transfer of Mass and Heat in the Cathode of Polymer Electrolyte Membrane Fuel Cell. [Thesis]. University of Waterloo; 2007. Available from: http://hdl.handle.net/10012/3139

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Penn State University

25. Al Ghamdi, Bander Nasser. Examination of Unconventional Phenomena in Naturally Fracture Liquid-rich Gas Reservoirs: Single-block Compositional Model.

Degree: 2016, Penn State University

URL: https://submit-etda.libraries.psu.edu/catalog/28035

► Liquid-rich gas reservoir development is highly dependent on the thermodynamic behavior of the fluids-in-place. During the depletion of liquid-rich gas reservoirs, the gas condenses as… (more)

▼ Liquid-rich gas reservoir development is highly dependent on the thermodynamic behavior of the fluids-in-place. During the depletion of liquid-rich gas reservoirs, the gas condenses as the pressure of the reservoir reduces below the hydrocarbon dew-point pressure, which introduces a liquid phase called retrograde condensate. In such conditions, the productivity experiences a reduction in recovery due to the appearance of condensate near the production channels, which in turn reduces the overall flow of hydrocarbons to the surface. A numerical compositional reservoir simulation was developed in-house to simulate the productivity of liquid-rich gas reservoirs in tight formations. The capability of the simulator proved to be successful after simulating a hypothetical case of a 2-D tight liquid-rich gas reservoir using the in-house simulator against commercial software CMG. The results of both simulators came into agreement with one producer well being put on production at a constrained bottom-hole flowing pressure of 1500 psia. The validation of the basic framework of the in-house simulator has provided the necessary confidence to extend the development of more complex models. The impact of capillary pressure on phase behavior was explored using an in-house generated coupled phase behavior model with a capillary pressure equation. The influence of capillary pressure was examined against different sets of composition combinations in different reservoir settings. The capillary forces' extents were highly dependent on composition combinations and pore radiuses. Mixtures with higher volatile concentrations showed the highest capillary forces. The enhancement in condensate propagation, resistance to gas flow, and impact on recovery were explored at 10 nm and 20 nm pore radiuses. The investigation suggested that interfacial tensions implied greater influence on the flow behavior in oil-dominated systems than in gas-dominated conditions. Evaluating the flow performance of unconventional phenomena in liquid-rich gas reservoirs was extended to include diffusion while activating capillary forces. The results showed higher domination of diffusion on reservoir performance which provided additional fluid recovery. Subsequently, the enhanced withdrawal of fluid dismissed the impact of capillary forces on gas flow and the impact of condensate blockage. Advisors/Committee Members: Luis F Ayala H, Dissertation Advisor/Co-Advisor, Luis F Ayala H, Committee Chair/Co-Chair, Turgay Ertekin, Committee Member, Eugene C Morgan, Committee Member, Mathieu Philippe Stienon, Committee Member.

Subjects/Keywords: Liquid-Rich reservoirs; Diffusion; Naturally fractured systems; Capillary pressure; Unconventional reservoirs; Compositional

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APA (6^th Edition):

Al Ghamdi, B. N. (2016). Examination of Unconventional Phenomena in Naturally Fracture Liquid-rich Gas Reservoirs: Single-block Compositional Model. (Thesis). Penn State University. Retrieved from https://submit-etda.libraries.psu.edu/catalog/28035

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Al Ghamdi, Bander Nasser. “Examination of Unconventional Phenomena in Naturally Fracture Liquid-rich Gas Reservoirs: Single-block Compositional Model.” 2016. Thesis, Penn State University. Accessed January 24, 2021. https://submit-etda.libraries.psu.edu/catalog/28035.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Al Ghamdi, Bander Nasser. “Examination of Unconventional Phenomena in Naturally Fracture Liquid-rich Gas Reservoirs: Single-block Compositional Model.” 2016. Web. 24 Jan 2021.

Vancouver:

Al Ghamdi BN. Examination of Unconventional Phenomena in Naturally Fracture Liquid-rich Gas Reservoirs: Single-block Compositional Model. [Internet] [Thesis]. Penn State University; 2016. [cited 2021 Jan 24]. Available from: https://submit-etda.libraries.psu.edu/catalog/28035.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Al Ghamdi BN. Examination of Unconventional Phenomena in Naturally Fracture Liquid-rich Gas Reservoirs: Single-block Compositional Model. [Thesis]. Penn State University; 2016. Available from: https://submit-etda.libraries.psu.edu/catalog/28035

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Penn State University

26. Abah, Alphonsus Igoche. Effect of Multi-phase Flow on Recovery of Fracture Fluid and Gas in Marcellus Shale Reservoirs.

Degree: 2014, Penn State University

URL: https://submit-etda.libraries.psu.edu/catalog/21276

► ABSTRACT Hydraulic fracture treatment of shale gas wells does not always yield the expected folds of increase in gas production. Low production rates could be… (more)

▼ ABSTRACT Hydraulic fracture treatment of shale gas wells does not always yield the expected folds of increase in gas production. Low production rates could be attributed to a number of factors like proppant crushing, proppant diagenesis, clay swelling and rock-fluid interactions based on previous work (Osholake, Wang, Ertekin, 2011; Yue, 2012). In this research work, we evaluated the effect of multi-phase flow, capillary pressure, length of shut-in time and proppant crushing on performances of hydraulically fractured Marcellus Shale wells. To accomplish this, a 2-dimensional, 2-phase water-gas model was developed using a commercial software. Three hydraulic fracture (HF1, HF2, HF3) with different network sizes were used to simulate the effect of the above factors on long-term gas production and fracture fluid recovery from hydraulically fractured Marcellus wells. Two types of proppants were used to evaluate the effect of conductivity on the impact of the factors being studied. With high conductivity 20/40 ceramics proppant in the hydraulic fractures, long term gas production was not affected by any of the factors studied. With 20/40 ceramics fracture fluid recovery on the other hand was affected by all the factors studied. Shut-in time had the greatest effect on fracture fluid recovery. Less than 1% of the fracture fluid used for treating the well was recovered after 1-year shut-in. With the less conductive 100 mesh sand, long term gas production and fracture fluid recovery were affected by some of the factors studied. Multi-phase flow and proppant crushing were found to decrease cumulative gas production. Effect of proppant crushing on gas production was greater compared to multi-phase flow. In twenty years of production, multi-phase flow decreased gas production by 1.8%, 2.2% and 3.9% in HF1, HF2 and HF3 respectively while proppant crushing decreased gas production by 3.5%, 3.9% and 5.8% in HF1, HF2 and HF3 respectively. Capillary pressure had little or no effect on long-term gas production, but was observed to delay gas peak during initial production. Long term gas production was unaffected by shut-in time. Fracture fluid recovery was decreased by high capillary pressure, increased shut-in time and proppant crushing. After one year of shut-in, less than 1 % of fracture fluid was recovered. The new understanding helps engineers design better treatment and flowback operation in Marcellus. Advisors/Committee Members: Yilin Wang, Thesis Advisor/Co-Advisor.

Subjects/Keywords: Hydraulic; fracture; fracturing; marcellus; proppant; multi-phase flow; shut-in; capillary pressure

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Abah, A. I. (2014). Effect of Multi-phase Flow on Recovery of Fracture Fluid and Gas in Marcellus Shale Reservoirs. (Thesis). Penn State University. Retrieved from https://submit-etda.libraries.psu.edu/catalog/21276

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Abah, Alphonsus Igoche. “Effect of Multi-phase Flow on Recovery of Fracture Fluid and Gas in Marcellus Shale Reservoirs.” 2014. Thesis, Penn State University. Accessed January 24, 2021. https://submit-etda.libraries.psu.edu/catalog/21276.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Abah, Alphonsus Igoche. “Effect of Multi-phase Flow on Recovery of Fracture Fluid and Gas in Marcellus Shale Reservoirs.” 2014. Web. 24 Jan 2021.

Vancouver:

Abah AI. Effect of Multi-phase Flow on Recovery of Fracture Fluid and Gas in Marcellus Shale Reservoirs. [Internet] [Thesis]. Penn State University; 2014. [cited 2021 Jan 24]. Available from: https://submit-etda.libraries.psu.edu/catalog/21276.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Abah AI. Effect of Multi-phase Flow on Recovery of Fracture Fluid and Gas in Marcellus Shale Reservoirs. [Thesis]. Penn State University; 2014. Available from: https://submit-etda.libraries.psu.edu/catalog/21276

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Purdue University

27. Griessman, Alex Ross. Modeling of Shrinkage During Desiccation of Extruded Durum Semolina Pasta.

Degree: MS, Agricultural and Biological Engineering, 2016, Purdue University

URL: https://docs.lib.purdue.edu/open_access_theses/1188

Extruded durum semolina pasta was dried over saturated salt solutions, and the Advisors/Committee Members: Martin R Okos, Ganesan Narsimhan, Osvaldo Campanella.

Subjects/Keywords: Capillary Pressure; Finite Element; Pasta; Shrinkage

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APA (6^th Edition):

Griessman, A. R. (2016). Modeling of Shrinkage During Desiccation of Extruded Durum Semolina Pasta. (Thesis). Purdue University. Retrieved from https://docs.lib.purdue.edu/open_access_theses/1188

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Griessman, Alex Ross. “Modeling of Shrinkage During Desiccation of Extruded Durum Semolina Pasta.” 2016. Thesis, Purdue University. Accessed January 24, 2021. https://docs.lib.purdue.edu/open_access_theses/1188.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Griessman, Alex Ross. “Modeling of Shrinkage During Desiccation of Extruded Durum Semolina Pasta.” 2016. Web. 24 Jan 2021.

Vancouver:

Griessman AR. Modeling of Shrinkage During Desiccation of Extruded Durum Semolina Pasta. [Internet] [Thesis]. Purdue University; 2016. [cited 2021 Jan 24]. Available from: https://docs.lib.purdue.edu/open_access_theses/1188.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Griessman AR. Modeling of Shrinkage During Desiccation of Extruded Durum Semolina Pasta. [Thesis]. Purdue University; 2016. Available from: https://docs.lib.purdue.edu/open_access_theses/1188

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

University of Wisconsin – Milwaukee

28. Etemadi, Reihaneh. Effect of Processing Parameters and Matrix Shrinkage on Porosity Formation During Synthesis of Metal Matrix Composites with Dual-scale Fiber Reinforcements Using Pressure Infiltration Process.

Degree: MS, Engineering, 2014, University of Wisconsin – Milwaukee

URL: https://dc.uwm.edu/etd/686

► This is first such study on porosity formation phenomena observed in dual-scale fiber preforms during the synthesis of metal matrix composites (MMCs) using the… (more)

Subjects/Keywords: Capillary Number; Dual-Scale; Metal Matrix Composite; Porosity; Pressure Infiltration Process; RTM; Engineering; Mechanical Engineering

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Etemadi, R. (2014). Effect of Processing Parameters and Matrix Shrinkage on Porosity Formation During Synthesis of Metal Matrix Composites with Dual-scale Fiber Reinforcements Using Pressure Infiltration Process. (Thesis). University of Wisconsin – Milwaukee. Retrieved from https://dc.uwm.edu/etd/686

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Etemadi, Reihaneh. “Effect of Processing Parameters and Matrix Shrinkage on Porosity Formation During Synthesis of Metal Matrix Composites with Dual-scale Fiber Reinforcements Using Pressure Infiltration Process.” 2014. Thesis, University of Wisconsin – Milwaukee. Accessed January 24, 2021. https://dc.uwm.edu/etd/686.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Etemadi, Reihaneh. “Effect of Processing Parameters and Matrix Shrinkage on Porosity Formation During Synthesis of Metal Matrix Composites with Dual-scale Fiber Reinforcements Using Pressure Infiltration Process.” 2014. Web. 24 Jan 2021.

Vancouver:

Etemadi R. Effect of Processing Parameters and Matrix Shrinkage on Porosity Formation During Synthesis of Metal Matrix Composites with Dual-scale Fiber Reinforcements Using Pressure Infiltration Process. [Internet] [Thesis]. University of Wisconsin – Milwaukee; 2014. [cited 2021 Jan 24]. Available from: https://dc.uwm.edu/etd/686.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Etemadi R. Effect of Processing Parameters and Matrix Shrinkage on Porosity Formation During Synthesis of Metal Matrix Composites with Dual-scale Fiber Reinforcements Using Pressure Infiltration Process. [Thesis]. University of Wisconsin – Milwaukee; 2014. Available from: https://dc.uwm.edu/etd/686

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

University of Vermont

29. George, Lindsay. Characterization of Unsaturated Soils Using Acoustic Techniques.

Degree: PhD, Civil and Environmental Engineering, 2009, University of Vermont

URL: https://scholarworks.uvm.edu/graddis/91

► Recently there has been a great interest in the ability to relate the hydro-mechanical properties of soils to their acoustic response. This ability could enhance… (more)

▼ Recently there has been a great interest in the ability to relate the hydro-mechanical properties of soils to their acoustic response. This ability could enhance high resolution non-destructive evaluation of the shallow subsurface, and would have applications in a variety of fields including groundwater and contaminant hydrogeology, oil recovery, soil dynamics, and the detection of buried objects. Groundwater hydrologists and environmental engineers are challenged with the task of characterizing the material, mechanical and hydraulic properties of the subsurface with limited information generally collected from discrete points. Geophysical testing offers a suite of measurement techniques that allow for the non destructive evaluation of potentially large areas in a continuous manner. Acoustic testing is one geophysical method used by many professions to characterize the subsurface. Unsaturated and multiphase flow modeling relies on the relationship between the capillary pressure and the level of saturation of the porous media. It has been previously suggested that this relationship may be non-unique and rate dependent. A theory which relates this dynamic relationship to the acoustic properties of the soil was developed by others. This research attempts to experimentally verify this theory by meeting the following three objectives: (1) develop an apparatus and procedure to collect acoustic waveforms on laboratory sized unsaturated soil samples, (2) develop a forward modeling technique using a one-dimensional wave propagation model as an alternative analysis method for waves collected on relatively small laboratory specimens, and (3) apply the theory to the measured acoustic data in an attempt to predict the dynamic behavior of the capillary pressure relationship. The acoustic data collected showed variation in compressional wave velocity and attenuation with saturation, and the trends were consistent with data collected by others in partially saturated rocks. The forward modeling technique was shown to provide objective results with reasonable accuracy and low computational time. The dynamic effects predicted with these acoustic measurements did not sufficiently explain the dynamic behavior seen in the laboratory. This is attributed to other causes of significant attenuation not accounted for in the wave propagation theory that was evaluated. Advisors/Committee Members: Dewoolkar, Mandar.

Subjects/Keywords: dynamic capillary pressure function; compressional velocity

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

George, L. (2009). Characterization of Unsaturated Soils Using Acoustic Techniques. (Doctoral Dissertation). University of Vermont. Retrieved from https://scholarworks.uvm.edu/graddis/91

Chicago Manual of Style (16^th Edition):

George, Lindsay. “Characterization of Unsaturated Soils Using Acoustic Techniques.” 2009. Doctoral Dissertation, University of Vermont. Accessed January 24, 2021. https://scholarworks.uvm.edu/graddis/91.

MLA Handbook (7^th Edition):

George, Lindsay. “Characterization of Unsaturated Soils Using Acoustic Techniques.” 2009. Web. 24 Jan 2021.

Vancouver:

George L. Characterization of Unsaturated Soils Using Acoustic Techniques. [Internet] [Doctoral dissertation]. University of Vermont; 2009. [cited 2021 Jan 24]. Available from: https://scholarworks.uvm.edu/graddis/91.

Council of Science Editors:

George L. Characterization of Unsaturated Soils Using Acoustic Techniques. [Doctoral Dissertation]. University of Vermont; 2009. Available from: https://scholarworks.uvm.edu/graddis/91

King Abdullah University of Science and Technology

30. Negara, Ardiansyah. Simulation of CO2 Injection in Porous Media with Structural Deformation Effect.

Degree: 2011, King Abdullah University of Science and Technology

URL: http://hdl.handle.net/10754/205791

► Carbon dioxide (CO2) sequestration is one of the most attractive methods to reduce the amount of CO2 in the atmosphere by injecting it into the… (more)

Subjects/Keywords: Carbon dioxide (CO2) sequestration; Two-phase flow; Cell-centered finite difference; IMPES; Deformation; Capillary pressure

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APA · Chicago · MLA · Vancouver · CSE | Export to Zotero / EndNote / Reference Manager

APA (6^th Edition):

Negara, A. (2011). Simulation of CO2 Injection in Porous Media with Structural Deformation Effect. (Thesis). King Abdullah University of Science and Technology. Retrieved from http://hdl.handle.net/10754/205791

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Chicago Manual of Style (16^th Edition):

Negara, Ardiansyah. “Simulation of CO2 Injection in Porous Media with Structural Deformation Effect.” 2011. Thesis, King Abdullah University of Science and Technology. Accessed January 24, 2021. http://hdl.handle.net/10754/205791.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

MLA Handbook (7^th Edition):

Negara, Ardiansyah. “Simulation of CO2 Injection in Porous Media with Structural Deformation Effect.” 2011. Web. 24 Jan 2021.

Vancouver:

Negara A. Simulation of CO2 Injection in Porous Media with Structural Deformation Effect. [Internet] [Thesis]. King Abdullah University of Science and Technology; 2011. [cited 2021 Jan 24]. Available from: http://hdl.handle.net/10754/205791.

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Council of Science Editors:

Negara A. Simulation of CO2 Injection in Porous Media with Structural Deformation Effect. [Thesis]. King Abdullah University of Science and Technology; 2011. Available from: http://hdl.handle.net/10754/205791

Note: this citation may be lacking information needed for this citation format:
Not specified: Masters Thesis or Doctoral Dissertation

Open Access Theses and Dissertations