**Current Filters**

**Peer Reviewed**

**Source**

**SPE Disciplines**

**Journal**

**Conference**

- 19th Formation Evaluation Symposium of Japan (1)
- 2006 SEG Annual Meeting (1)
- 2016 SEG International Exposition and Annual Meeting (1)
- 45th U.S. Rock Mechanics / Geomechanics Symposium (1)
- 46th U.S. Rock Mechanics/Geomechanics Symposium (1)
- Annual Technical Meeting (1)
- Canadian International Petroleum Conference (3)
- DC Rocks 2001, The 38th U.S. Symposium on Rock Mechanics (USRMS) (1)
- European Petroleum Conference (2)
- EUROPEC/EAGE Conference and Exhibition (1)
- Fall Meeting of the Society of Petroleum Engineers of AIME (1)
- International Petroleum Technology Conference (1)
- International Thermal Operations and Heavy Oil Symposium (1)
- Latin American & Caribbean Petroleum Engineering Conference (1)
- Latin American and Caribbean Petroleum Engineering Conference (1)
- Mathematical Methods in Fluid Dynamics and Simulation of Giant Oil and Gas Reservoirs (1)
- North American Unconventional Gas Conference and Exhibition (1)
- Offshore Technology Conference (1)
- Permian Basin Oil and Gas Recovery Conference (1)
- SPE Annual Technical Conference and Exhibition (12)
- SPE Asia Pacific Conference on Integrated Modelling for Asset Management (1)
- SPE Asia Pacific Unconventional Resources Conference and Exhibition (1)
- SPE Eastern Regional Conference and Exhibition (1)
- SPE Eastern Regional Meeting (1)
- SPE Europec/EAGE Annual Conference (1)
- SPE EUROPEC/EAGE Annual Conference and Exhibition (1)
- SPE Gas Technology Symposium (2)
- SPE International Petroleum Conference and Exhibition in Mexico (1)
- SPE Latin America Petroleum Engineering Conference (1)
- SPE Latin America/Caribbean Petroleum Engineering Conference (1)
- SPE Mid-Continent Gas Symposium (1)
- SPE Middle East Unconventional Gas Conference and Exhibition (1)
- SPE Reservoir Characterization and Simulation Conference and Exhibition (1)
- SPE Reservoir Simulation Symposium (2)
- SPE Symposium on Reservoir Simulation (2)
- SPE Western Regional Meeting (2)
- SPE/DOE Improved Oil Recovery Symposium (1)
- The 35th U.S. Symposium on Rock Mechanics (USRMS) (1)
- The Twenty-second International Offshore and Polar Engineering Conference (3)
- The Twenty-third International Offshore and Polar Engineering Conference (1)

**Publisher**

- American Rock Mechanics Association (4)
- International Petroleum Technology Conference (1)
- International Society of Offshore and Polar Engineers (4)
- Offshore Technology Conference (1)
- Petroleum Society of Canada (8)
- Society of Exploration Geophysicists (2)
- Society of Petroleum Engineers (61)
- Society of Petrophysicists and Well-Log Analysts (1)

**Theme**

**Author**

- Akkutlu, I.Y. (1)
- Almada, M.B. Pingo (1)
- Ansari, Rafay Z. (1)
- Arbogast, Todd (1)
- Arbogast, Todd J. (1)
- Babadagli, Tayfun (1)
- Babchin, A. (1)
- Bakke, Stig (1)
- Bakken, H. (1)
- Basu, Debashis (1)
- Bedrikovetsky, P. (1)
- Bijeljic, Branko (1)
- Blunt, Martin Julian (1)
- Bosio, Jacques (1)
- Brancolini, A. (1)
- Britto, P.R.F. (1)
- Bruining, J. (1)
- Bruining, Johannes (2)
- Bryant, Steven L. (1)
- Chatzis, I. (1)
- Chierici, Gian Luigi (1)
- Chraibi, Mehdi (1)
- Civan, F. (1)
- Civan, Faruk (2)
- Claridge, E.L. (1)
- Das, Kaushik (1)
- Davy, C.A. (1)
- Dawe, R.A. (2)
- Delliste, Arnaud M. (1)
- Donmez, A. (1)
- Doonechaly, Nima Gholizadeh (1)
- Dullien, F.A.L. (1)
- Dupuy, Michel P. (1)
- Duveau, G. (1)
- Ebeltoft, E. (1)
- El-Amin, M.F. (1)
- El-amin, Mohamed Fathy (1)
- Erkal, A. (1)
- Evans, R.D. (2)
- Fanchi, John R. (1)
- Farajzadeh, Rouhollah (2)
- Fathi, E. (1)
- Firoozabadi, A. (1)
- Fleury, M. (1)
- Franco, Fabienne (1)
- Gagneux, G. (1)
- Georgi, D.T. (1)
- Glbrandsen, S. (1)
- Granet, S. (1)
- Grattoni, C.A. (1)
- Green, Steve (1)
- Gregor, J. (1)
- Grigg, Reid B. (1)
- Guevara-Jordan, Juan Manuel (1)
- Gunde, Akshay (1)
- Gurakin, G. (1)
- Gurevich, Boris (1)
- Hardy, H.H. (1)
- Haugse, Vidar (2)
- Herring, T.R. (1)
- Hwang, Myung K. (1)
- Ioannidis, M.A. (1)
- Ishibashi, Takuya (1)
- Iversen, J.E. (1)
- Jakobsen, Morten (1)
- Janetzke, Ron (1)
- Javadpour, F. (2)
- Jennings, James W. (1)
- Jhonnanthan, Arteaga-Arispe (1)
- Jiang, Ruizhong (1)
- Johns, Russell T. (1)
- Johnsen, O. (1)
- Kantzas, A. (1)
- Karambas, Th. A. (1)
- Kardjilov, N. (1)
- Kasap, Ekrem (1)
- Keenan, Philip T. (1)
- Khachkova, Tatyana (1)
- Killough, J.E. (1)
- Kim, F.H. (1)
- King, M.J. (1)
- Knight, S. (1)
- Koftis, Ch. (1)
- Kolyukhin, Dmitry (1)
- Komai, T. (1)
- Kossack, Charles Ayres (1)
- Koutandos, E. (1)
- Kulatilake, P.H.S.W. (1)
- Kulkarni, R.N. (1)
- Kwiecien, M.J. (1)
- La Pointe, Paul R. (1)
- Lai, Bitao (1)
- Lake, Larry W. (1)
- Lebedev, Maxim (1)
- Lee, Glori (1)
- Lee, S.H. (1)
- Lefevere, A.M. (1)
- Li, Jun (1)
- Li, Kewen (1)
- Li, Linkai (1)
- Liang, Dongfang (1)
- Lisitsa, Vadim (1)
- M'Jahad, S. (1)
- Macdonald, I.F. (1)
- Madaune-Tort, M. (1)
- Malama, B. (1)
- Manke, I. (1)
- Mannseth, T. (1)
- Manrique, J.F. (1)
- Martinsen, Rune (1)
- McKean, H.C. (1)
- Mehmani, Ayaz (1)
- Mejia, Gerardo (1)
- Merxhani, Andi (1)
- Milliken, W.J. (1)
- Miskimins, Jennifer Lynne (1)
- Mitra, Sushanta (1)
- Moctezuma-Berthier, A. (1)
- Mostaghimi, Peyman (1)
- Mourits, F.M. (1)
- Mykkeltveit, J. (1)
- Nasr, T. (1)
- Negara, Ardiansyah (1)
- Negara, Ardiansyah Kusuma (1)
- Nielsen, Russell L. (1)
- Nordtvedt, J.E. (4)
- Numbere, D.T. (1)
- Ohsaki, Yutaka (1)
- Onur, M. (1)
- Oren, Paul Eric (1)
- Ortiz-Arango, J.D. (1)
- Palmgren, C.T.S. (1)
- Papatzacos, Paul (2)
- Paruchuri, Ramoj (1)
- Patzek, Tad W. (1)
- Patzek, Tadeusz Wiktor (1)
- Peaceman, D.W. (1)
- Penumadu, D. (1)
- Prinos, P. (1)
- Prodanovic, Masa (1)
- Rahman, Sheik (1)
- Rame, Marcelo (1)
- Ramstad, Thomas (1)
- Reshetova, Galina (1)
- Rian, Dag Terje (1)
- Richmond, P.C. (1)
- Rodrigues, J.R.P. (1)
- Rose, Walter (2)
- Sakamoto, Y. (1)
- Sakurai, Keisuke (1)
- Salama, Amgad (3)
- Salimi, Hamidreza (1)
- Sammon, Peter H. (1)
- Sandvik, Arnfinn (1)
- Satik, Cengiz (1)
- Schulz, V.P. (1)
- Settari, Antonin (1)
- Shan, Lijun (1)
- Shao, J.F. (1)
- Sheppard, Adrian (1)
- Silin, Dmitriy Borisovich (1)
- Skjaeveland, S.M. (1)
- SkjÃ¦veland, Svein M. (1)
- Skoczylas, F. (1)
- Sovold, Knut (1)
- Stamatakos, John (1)
- Sultan, Abdullah S. (1)
- Sun, Shuyu (3)
- Sylte, A. (2)
- Talandier, J. (1)
- Tamagawa, Tetsuya (1)
- Tan, C.T. (1)
- Tanaka, A. (1)
- Tcheverda, Vladimir (1)
- Tek, M.R. (1)
- Thomas, Andrew L. (1)
- Tokan-lawal, Adenike (1)
- Tsuchiya, Noriyoshi (1)
- Ucan, S. (1)
- Ucan, Sezai (1)
- Urkedal, H. (1)
- Van Batenburg, D.W. (1)
- van Daalen, F. (1)
- van Domselaar, H.R. (1)
- van Lingen, P.P. (1)
- Vatne, K.O. (1)
- Wan, Decheng (1)
- Wang, Jifei (1)
- Wang, Junjian (1)
- Wang, Ruiheng (1)
- Watanabe, Noriaki (1)
- Watson, A.T. (3)
- Watsons, A.T. (1)
- Wheeler, Mary F. (1)
- Wiegmann, A. (1)
- Wille, S.A. (1)
- Xie, Lisha (1)
- Xu, Jianchun (1)
- Yagi, Masahiko (1)
- Yang, Pin-Huel (1)
- Yotov, Ivan (1)
- Yuan, J. (1)
- Yuan, Yudong (1)
- Zaleski, Stephane (1)
- Zeybek, M. (1)
- Zhang, Liying (1)
- Zitha, Pacelli Lidio Jose (1)

**Concept Tag**

- approach (4)
- Artificial Intelligence (5)
- Behavior (3)
- block (4)
- boundary (17)
- boundary condition (5)
- breakthrough (4)
- calculation (4)
- case (7)
- chemical flooding (4)
- coefficient (9)
- concentration (9)
- condensate reservoir (3)
- condition (20)
- core (8)
- curve (6)
- darcy (4)
- data (7)
- difference (6)
- diffusion (6)
- direction (5)
- dispersion (5)
- displacement (10)
- distribution (11)
- effect (15)
- element (4)
- equation (35)
- estimate (4)
- estimation (5)
- experiment (15)
- field (7)
- Fig (14)
- Figure (20)
- flow in porous media (82)
- flow metering (11)
- Fluid Dynamics (82)
- formation evaluation (67)
- function (17)
- gas (7)
- gas injection method (4)
- grid (8)
- heterogeneity (8)
- history matching (4)
- image (5)
- imbibition (4)
- injection (6)
- machine learning (4)
- measurement (4)
- method (17)
- mobility (5)
- model (27)
- multiphase flow (34)
- network (4)
- number (5)
- oil (10)
- optimization problem (5)
- parameter (9)
- permeability (57)
- permeability curve (8)
- Phase (3)
- pore (9)
- pore space (4)
- pressure (45)
- pressure curve (5)
- problem (5)
- process (5)
- produced water (6)
- production control (37)
- production logging (19)
- production monitoring (37)
- profile (6)
- property (7)
- PVT measurement (11)
- rate (5)
- reservoir (6)
- reservoir simulation (82)
- result (8)
- sample (7)
- saturation (36)
- Saturation profile (5)
- scale (4)
- scaling method (12)
- shale gas (5)
- simulator development (10)
- solution (14)
- SPE (5)
- State (3)
- surface (4)
- system (8)
- Table (3)
- time (7)
- transport (7)
- value (15)
- velocity (17)
- viscosity (7)
- voxel (4)
- water (18)
- waterflooding (11)
- Wave (4)
- well (7)

**Industry**

**Oilfield Places**

**Technology**

**File Type**

Lisitsa, Vadim (Institute of Petroleum Geology and Geophysics SB RAS) | Khachkova, Tatyana (Institute of Petroleum Geology and Geophysics SB RAS) | Kolyukhin, Dmitry (Institute of Petroleum Geology and Geophysics SB RAS) | Gurevich, Boris (Curtin University) | Lebedev, Maxim (Curtin University) | Reshetova, Galina (Institute of Computational Mathematics and Mathematical Geophysics SB RAS) | Tcheverda, Vladimir (Institute of Geophysics)

Typically the resolution of micro-CT scans of the rock samples and the physical size of the studied volume are linearly connected; i.e. improvement in the resolution requires the sample size reduction. In this paper we consider four images of the Bentheimer outcrop sandstone sample acquired with different resolution to determine the effect of the image scale on the geometrical, topological, and transport properties of the digital core sample. To overcome the strict restriction on the sample size and to approach the representative volumes we suggest using statistical modelling of the images using truncated Gaussian simulation method. This approach preserves total porosity of the sample and reciprocal pore-to-core distribution, however it does not preserve advanced geometrical and topological properties of the pore space such as Minkowski functionals values and Betti numbers of the pore spaces. Nevertheless, permeability and tortuosity of the original images are well matched by synthetic images.

Presentation Date: Monday, October 17, 2016

Start Time: 3:45:00 PM

Location: 167

Presentation Type: ORAL

flow in porous media, Fluid Dynamics, formation evaluation, image, machine learning, number, permeability, pore space, porosity, property, representative, Representative Volume, reservoir simulation, resolution, sample, sandstone, scale dependency, scaling method, statistically, transport property, volume, voxel

SPE Disciplines:

- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Fluid Characterization > Fluid modeling, equations of state (0.63)
- Reservoir Description and Dynamics > Reservoir Simulation > Scaling methods (0.52)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (0.47)

Li, Jun (Center for Integrative Petroleum Research, King Fahd University of Petroleum & Minerals) | Sultan, Abdullah S. (Center for Integrative Petroleum Research & Department of Petroleum Engineering, King Fahd University of Petroleum & Minerals)

The permeability variation of shale gas with pressure is an important input data in the predictions of well performance for optimizing production. We present a novel pore-scale simulation scheme to accurately compute the permeabilities at different pressure conditions by using the Fortran parallel software

adsorption layer, Boltzmann, computational, condition, Dsbgk, DSBGK simulation, equation, flow in porous media, Fluid Dynamics, formation evaluation, model, permeability, pore, pressure, produced water, reservoir simulation, scaling method, shale gas, Simulation, simulator development, velocity, voxel

SPE Disciplines:

- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)

Yuan, Yudong (School of Petroleum Engineering, University of New South Wales) | Rahman, Sheik (School of Petroleum Engineering, University of New South Wales) | Wang, Junjian (School of Petroleum Engineering, University of New South Wales) | Doonechaly, Nima Gholizadeh (School of Petroleum Engineering, University of New South Wales)

Characterization of flow processes in multi-scale porous system (nanopores to mesopores) in tight rocks, such as the shales, is challenging because of the coexistence of various flow regimes in the porous media. Although some methods based on dusty gas model (DGM) have been applied to determine the apparent gas permeability of shales (

boundary, diffusion, distribution, effect, flow in porous media, Fluid Dynamics, formation evaluation, gas injection method, Knudsen, lattice Boltzmann, model, permeability, pore, pressure, produced water, production control, production logging, production monitoring, regime, reservoir simulation, shale gas, surface diffusion, velocity, viscosity

Oilfield Places:

- Oceania > Australia > Western Australia > North West Shelf > Carnarvon Basin (0.99)
- North America > United States > Arkansas > Fayetteville Shale (0.99)
- Oceania > Australia > Western Australia > Southern Carnarvon Basin > Muderong Shale (0.98)

SPE Disciplines:

- Reservoir Description and Dynamics > Unconventional and Complex Reservoirs > Shale gas (1.00)
- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)

Sakurai, Keisuke (Tohoku University) | Watanabe, Noriaki (Tohoku University) | Ishibashi, Takuya (Tohoku University) | Tsuchiya, Noriyoshi (Tohoku University) | Ohsaki, Yutaka (JAPEX) | Tamagawa, Tetsuya (JAPEX) | Yagi, Masahiko (JAPEX)

**Abstract **

Two-phase flows through fractures in subsurface rocks are of great importance in several domains. Despite this importance few studies have been conducted, and the results presented in the literature seem to be contradictory. So far, two-phase fracture flows are not well understood. In our recent study, it was indicated that relative permeability curves for fractures in rocks under confining pressure may different from the X model, the viscous coupling model, and even the Corey model, due to strong interference between phases by capillarity in the 2-D flow field. However, it was difficult to make a concrete conclusion due to the limited results. In the present study, oil (n-decane)-water relative permeability curves of fractures having different intrinsic permeabilities (i.e., aperture distributions) in granite and limestone under confining pressure has been investigated. First of all, no significant difference was found between fractures in the present granite and limestone. In case of the fracture having the highest intrinsic permeability (4 × 10-10 m2), there was no significant influence of capillarity due to bigger apertures, resulting in X-type relative permeability curves. On the other hand, in case of the fractures having lower intrinsic permeabilities (1 × 10-11 m2 and 4 × 10-11 m2), there was significant influence between phases by capillarity due to smaller apertures, resulting in the Corey-type and V-type (named in the present study) relative permeability curves depending on intrinsic permeability. The V-type relative permeability curves with the strongest interference between phases were found at the smallest intrinsic permeability. It has been revealed that there are three types of relative permeability curves for subsurface fractures depending on their intrinsic permeabilities (i.e., aperture distributions).

aperture, aperture distribution, capillarity, displacement, distribution, Figure, flow in porous media, Fluid Dynamics, formation evaluation, fracture, granite, limestone, model, multiphase flow, permeability, permeability curve, permeability measurement, pressure, production control, production logging, production monitoring, relation, reservoir simulation, shear

SPE Disciplines:

- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (0.69)

Negara, Ardiansyah (King Abdullah University of Science and Technology) | Salama, Amgad (King Abdullah University of Science and Technology) | Sun, Shuyu (King Abdullah University of Science and Technology)

**Abstract**

Anisotropy of hydraulic properties of subsurface geologic formations is an essential feature that has been established as a consequence of the different geologic processes that they undergo during the longer geologic time scale. With respect to petroleum reservoirs, in many cases, anisotropy plays significant role in dictating the direction of flow that becomes no longer dependent only on the pressure gradient direction but also on the principal directions of anisotropy. Furthermore, in complex systems involving the flow of multiphase fluids in which the gravity and the capillarity play an important role, anisotropy can also have important influences.

Therefore, there has been great deal of motivation to consider anisotropy when solving the governing conservation laws numerically. Unfortunately, the two-point flux approximation of finite difference approach is not capable of handling full tensor permeability fields. Lately, however, it has been possible to adapt the multipoint flux approximation that can handle anisotropy to the framework of finite difference schemes. In multipoint flux approximation method, the stencil of approximation is more involved, i.e., it requires the involvement of 9-point stencil for the 2-D model and 27-point stencil for the 3-D model. This is apparently challenging and cumbersome when making the global system of equations.

In this work, we apply the equation-type approach, which is the experimenting pressure field approach that enables the solution of the global problem breaks into the solution of multitude of local problems that significantly reduce the complexity without affecting the accuracy of numerical solution. This approach also leads in reducing the computational cost during the simulation.

We have applied this technique to a variety of anisotropy scenarios of 3-D subsurface flow problems and the numerical results demonstrate that the experimenting pressure field technique fits very well with the multipoint flux approximation method. Furthermore, the numerical results explicitly emphasize that anisotropy could not be ignored for the proper model of subsurface flow.

SPE Disciplines:

- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)

Technology:

- IT > AI > Representation & Reasoning > Uncertainty (0.81)
- IT > AI > Representation & Reasoning > Optimization (0.81)

ABSTRACT

In this paper, a transient incompressible viscous fluid flow is considered, and the ALE (Arbitrary Lagrangian-Eulerian) moving mesh method is applied to simulate the wave generation due to body motion near the free surface. The algorithm consists of three stages in each time step: a) the incompressible Navier-Stokes equations in the ALE frame are solved by finite element method (FEM) over the whole domain, while wave absorption being considered as well; b) the fluid velocities are used for updating the positions of the free surface nodes; c) the interior nodes are moved by solving a pseudo elastic problem so as to minimize mesh distortion. With the numerical method described above, free surface flows around 2D NACA0012 hydrofoil under different Froude numbers, submerged depths and attack angles are systematically investigated, respectively.

SPE Disciplines:

- Reservoir Description and Dynamics > Reservoir Simulation (0.65)
- Management and Information > Information Management and Systems (0.64)
- Reservoir Description and Dynamics > Reservoir Characterization (0.47)
- (2 more...)

Technology:

- IT > Mathematics Of Computing (0.41)
- IT > AI (0.36)

El-Amin, M.F. (King Abdullah University of Science and Technology) | Sun, Shuyu (King Abdullah University of Science and Technology) | Salama, Amgad (King Abdullah University of Science and Technology)

Geological storage of anthropogenic CO_{2} emissions in deep saline aquifers has recently received tremendous attention in the scientific literature. Injected CO_{2 }plume buoyantly accumulates at the top part of the deep aquifer under a sealing cap rock, and some concern that the high-pressure CO_{2} could breach the seal rock. However, CO_{2} will diffuse into the brine underneath and generate a slightly denser fluid that may induce instability and convective mixing. Onset times of instability and convective mixing performance depend on the physical properties of the rock and fluids, such as permeability and density contrast. The novel idea is to adding nanoparticles to the injected CO_{2} to increase density contrast between the CO_{2}-rich brine and the underlying resident brine and, consequently, decrease onset time of instability and increase convective mixing.

As far as it goes, only few works address the issues related to mathematical and numerical modeling aspects of the nanoparticles transport phenomena in CO_{2} storages. In the current work, we will present mathematical models to describe the nanoparticles transport carried by injected CO_{2} in porous media. Buoyancy and capillary forces as well as Brownian diffusion are important to be considered in the model. IMplicit Pressure Explicit Saturation-Concentration (IMPESC) scheme is used and a numerical simulator is developed to simulate the nanoparticles transport in CO_{2} storages.

SPE Disciplines:

- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)

Kim, F.H. (University of Tennessee) | Penumadu, D. (University of Tennessee) | Gregor, J. (University of Tennessee) | Kardjilov, N. (Helmholtz Center Berlin for Materials and Energy) | Manke, I. (Helmholtz Center Berlin for Materials and Energy) | Schulz, V.P. (Baden-Wuerttemberg Cooperative State University Mannheim) | Wiegmann, A. (Fraunhofer ITWM)

Soil is considered as a three-phase material containing solid, gas and liquid phases. The interactions between the different phases are of a critical importance in understanding soil deformation behavior. An arrangement of the three phases can be very complex, and it is very difficult to quantify.

SPE Disciplines:

- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Formation Evaluation & Management > Cross-well tomography (1.00)
- (2 more...)

Komai, T. (Research Institute for Geo-resources and Environment) | Sakamoto, Y. (Research Institute for Geo-resources and Environment) | Tanaka, A. (National Institute of Advanced Industrial Science and Technology (AIST))

Multi-phase flow behavior consisting of supercritical CO

In this study, we conducted experimental study on multi-phase flow behavior consisting of supercritical CO

Behavior, condition, differential pressure, Discharge, flow in porous media, flow metering, Fluid Dynamics, formation evaluation, injection, multiphase flow, multiphase flow behavior, permeability, permeability curve, pressure, production control, production monitoring, PVT measurement, reservoir simulation, sand, sand grain diameter, saturation, silica sand, subsurface storage, water, water saturation, waterflooding

SPE Disciplines:

- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Multiphase flow (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (1.00)
- (3 more...)

A numerical model is established and validated to study the behavior of porous seabed under solitary wave propagation. Using Biot''s poro-elastic theory, the problem is formulated as a two dimensional plane strain problem, and it is modelled using the Finite Element Method. The responses due to the solitary wave are compared with those of linear waves of the same height. It is found that regardless of the wave period, stresses due to solitary waves are generally larger. Implications on liquefaction need further investigation.

The present study examines the problem of the dynamic loading of a linear elastic isotropic seabed caused by solitary waves. The examination of the seabed response to wave induced loads is of interest to marine geotechnical engineers and to coastal engineers due to the possible wave induced seabed damages in the vicinity of marine structures (Jeng, 2001). Solitary waves are often used as representatives of tsunamis (Liang, Borthwick and Rommer-Lee, 2011), which can be caused either by earthquakes or by submarine landslides (Lovholt, Habritz and Haugen, 2005). To the knowledge of the authors this is the first attempt to study the behavior of soil under solitary wave propagation. The problem of wave-seabed interaction is modeled using the Biot theory of consolidation (Biot, 1941) under plane strain conditions, ignoring accelerations due to fluid and soil motion. Mass conservation is expressed using the storage equation of Verruijt(1969). The wave-seabed interaction problem modeled using Biot''s consolidation theory has been investigated in the past, and many numerical and analytical techniques have been proposed to solve it. Theoretical solutions have been developed for the case of linear waves. Assuming soil of infinite depth, Yamamoto et al(1978) gave an analytical solution to the problem for the case of isotropic unsaturated medium, while Madsen (1978) considered a hydraulically anisotropic unsaturated seabed.

SPE Disciplines:

- Reservoir Description and Dynamics > Reservoir Simulation (1.00)
- Reservoir Description and Dynamics > Reservoir Characterization (1.00)
- Reservoir Description and Dynamics > Reservoir Fluid Dynamics > Flow in porous media (0.47)