Estimation of Relative Permeability in Nanoporous Samples and Modeling of Pressure Transient Response in Naturally Fractured Reservoirs

Ojha, Shiv Prakash

Estimation of Relative Permeability in Nanoporous Samples and Modeling of Pressure Transient Response in Naturally Fractured Reservoirs

dc.contributor.advisor	Misra, Siddharth
dc.contributor.author	Ojha, Shiv Prakash
dc.contributor.committeeMember	Rai, Chandra
dc.contributor.committeeMember	Devegowda, Deepak
dc.date.accessioned	2017-12-13T17:00:25Z
dc.date.available	2017-12-13T17:00:25Z
dc.date.issued	2017-12-15
dc.date.manuscript	2017-12-11
dc.description.abstract	Relative permeability and irreducible saturations of organic-rich shale samples from various formations from different maturity windows are estimated by processing the low-pressure nitrogen adsorption-desorption measurements. Using percolation theory, effective medium theory and critical path analysis along with bimodal fractal regime, we estimate relative permeability curves for 100 samples of Bakken, Eagle Ford, Woodford, and Wolfcamp formations. The process also allows estimation of percolation and fractal parameters like coordination number and fractal dimension which facilitate description of the pore network for these shale samples. Transport properties are compared across different windows of maturity. Subsequently, reservoir simulation is used to predict the biphasic production performances of the corresponding formations and correlate predictions with field performance in unconventional reservoirs. Pressure transient analysis (PTA) can describe properties of subsurface natural fractures. Multistencils fast marching (MFM) method provides a reliable way to analyze the effects of natural fractures on the time-varying drainage volume and pressure transient response due to a production/injection well. The method is validated in various heterogeneous reservoirs against the response of equivalent systems generated using the Kappa Saphir commercial software. We study the sensitivities of pressure transients to fracture characteristics, such as fracture length, fracture compressibility, fracture permeability, angle of orientation, and fracture volume fraction in the reservoir. In doing so, we identify diagnostic signatures associated with these fracture characteristics.	en_US
dc.identifier.uri	https://hdl.handle.net/11244/52773
dc.language	en_US	en_US
dc.subject	Relative Permeability	en_US
dc.subject	Adsorption	en_US
dc.subject	Pressure Transient Analysis	en_US
dc.subject	Fast Marching Method	en_US
dc.thesis.degree	Master of Science	en_US
dc.title	Estimation of Relative Permeability in Nanoporous Samples and Modeling of Pressure Transient Response in Naturally Fractured Reservoirs	en_US
ou.group	Mewbourne College of Earth and Energy::Mewbourne School of Petroleum and Geological Engineering	en_US