Publications
542 results found
Blunt M, Hilpert M, 2001, <i>Special issue</i> -: Pore-scale modeling -: Editorial, ADVANCES IN WATER RESOURCES, Vol: 24, Pages: 231-232, ISSN: 0309-1708
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- Citations: 6
Christie MA, Blunt MJ, 2001, Tenth SPE comparative solution project: A comparison of upscaling techniques, SPE Reservoir Evaluation and Engineering, Vol: 4, Pages: 308-316, ISSN: 1094-6470
This paper presents the results of the 10th SPE Comparative Solution Project on Upscaling. Two problems were chosen. The first problem was a small 2D gas-injection problem, chosen so that the fine grid could be computed easily and both upscaling and pseudoization methods could be used. The second problem was a waterflood of a large geostatistical model, chosen so that it was hard (though not impossible) to compute the true fine-grid solution. Nine participants provided results for one or both problems. Copyright © 2001 Society of Petroleum Engineers.
Hughes RG, Blunt MJ, 2001, Network modeling of multiphase flow in fractures, ADVANCES IN WATER RESOURCES, Vol: 24, Pages: 409-421, ISSN: 0309-1708
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- Citations: 81
Hughes RG, Blunt MJ, 2000, Pore scale modeling of rate effects in imbibition, TRANSPORT IN POROUS MEDIA, Vol: 40, Pages: 295-322, ISSN: 0169-3913
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- Citations: 131
DiCarlo DA, Blunt MJ, 2000, Determination of finger shape using the dynamic capillary pressure, WATER RESOURCES RESEARCH, Vol: 36, Pages: 2781-2785, ISSN: 0043-1397
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- Citations: 21
Ronen D, Scher H, Blunt M, 2000, Field observations of a capillary fringe before and after a rainy season, JOURNAL OF CONTAMINANT HYDROLOGY, Vol: 44, Pages: 103-118, ISSN: 0169-7722
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- Citations: 40
Hui MH, Blunt MJ, 2000, Effects of wettability on three-phase flow in porous media, JOURNAL OF PHYSICAL CHEMISTRY B, Vol: 104, Pages: 3833-3845, ISSN: 1089-5647
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- Citations: 149
Schaefer CE, DiCarlo DA, Blunt MJ, 2000, Determination of water-oil interfacial area during 3-phase gravity drainage in porous media, JOURNAL OF COLLOID AND INTERFACE SCIENCE, Vol: 221, Pages: 308-312, ISSN: 0021-9797
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- Citations: 42
Di Carlo DA, Sahni A, Blunt MJ, 2000, The Effect of Wettability on Three-Phase Relative Permeability, Transport in Porous Media, Vol: 39, Pages: 347-366
Blunt MJ, 2000, An Empirical Model for Three-Phase Relative Permeability, SPE Journal, Vol: 5, Pages: 435-445
Zhou D, Dillard LA, Blunt MJ, 2000, A Physically Based Model of Dissolution of Nonaqueous Phase Liquids in the Saturated Zone, Transport in Porous Media, Vol: 39, Pages: 227-255
Dillard LA, Blunt MJ, 2000, Development of a pore network simulation model to study nonaqueous phase liquid dissolution, Water Resources Research, Vol: 36, Pages: 439-454
Di Carlo DA, Sahni A, Blunt MJ, 2000, Three-Phase Relative permeability of Water-Wet, Oil-Wet and Mixed-Wet Sandpacks, SPE Journal, Vol: 5, Pages: 82-91
Schaefer CE, Di Carlo DA, Blunt MJ, 2000, Experimental Measurement of Air-Water Interfacial Area During Gravity Drainage and Secondary Imbibition in Porous, Water Resources Research, Vol: 36, Pages: 885-890
Al-Hadhrami HS, Blunt MJ, 2000, Thermally Induced Wettability Alteration to Improve Oil Recovery in Fractured Reservoirs, SPE/DOE Improved Oil Recovery Symposium, Tulsa, OK, April
Keller AA, Blunt MJ, Roberts PV, 2000, Behavior of Nonaqueous Phase Liquids in Fractured Porous Media under Two-Phase Flow Conditions, Transport in Porous Media, Vol: 38, Pages: 189-203
Hui MH, Blunt MJ, 2000, Pore-Scale Modeling of Three-Phase Flow and the Effects of Wettability, SPE/DOE Improved Oil Recovery Symposium, Tulsa, OK, April
Blunt MJ, Jackson MD, 2000, Dynamic Upscaling from the Pore to the Reservoir Scale, 21st Annual International Energy Agency Workshop, Edinburgh, UK, 19-22 September
Blunt MJ, 1999, Empirical model for three-phase relative permeability
We present an empirical model for three-phase relative permeability that overcomes the limitations of current fomulations, such as Stone's methods. We provide a self-consistent treatment of wettability, changes in hydrocarbon composition, different saturation paths, and the trapping of oil, water and gas. The theoretical development is motivated by a review of recent three-phase experiments. The model is based on saturation-weighted interpolation between the two-phase values. To account for the effects of wettability we apply saturation-weighting to all three phases. By writing the relative permeabilities as unique functions of a flowing saturation, the model predicts the behavior for any sequence of saturation changes and accounts for trapping. Layer drainage, which allows oil relative permeabilities to be extrapolated to low saturation, is included for water-wet media. The model ensures smooth changes in relative permeability with changes in hydrocarbon composition and tends to the appropriate limits as the gas and oil become miscible. The model is tested against the data of Oak and co-workers. We show that it is necessary to include layer drainage and oil trapping to predict three-phase oil relative permeability at low oil saturation accurately.
Hughes RG, Blunt MJ, 1999, Pore-scale modeling of multiphase flow in fractures and matrix/fracture transfer
We use pore-scale network modeling to simulate imbibition in fractures and the matrix/fracture interaction. We represent the fracture as a two-dimensional lattice of conceptual pores and throats. We allow flow in connected wetting layers that occupy roughness and crevices in the pore space. We model piston-like advance with a capillary pressure that accounts for the curvature of the meniscus due to the fracture aperture, as well as the curvature of the wetting front in the fracture plane. We show that the model gives results that are insensitive to the resolution or pore spacing of the network. To account for viscous forces, the wetting phase pressure is computed assuming a fixed conductance in wetting layers. This pressure, in combination with the local capillary pressure, is used to determine the displacement sequence. A matrix is incorporated by surrounding the two-dimensional fracture plane by a three-dimensional network of pores and throats. We model multiphase flow in a real fracture using an aperture distribution obtained from CT scanning. The simulated saturation distributions agree with those measured using in situ imaging. We also study the matrix/fracture transfer in a large three-dimensional network.
Crane MJ, Blunt MJ, 1999, Streamline-based simulation of solute transport, WATER RESOURCES RESEARCH, Vol: 35, Pages: 3061-3078, ISSN: 0043-1397
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- Citations: 84
Schaefer CE, DiCarlo DA, Roberts PV, et al., 1999, DETERMINATION OF AIR-WATER INTERFACIAL AREA FOR DRAINAGE AND IMBIBITION IN UNSATURATED POROUS MEDIA, Pages: 93-97, ISSN: 0272-5673
Anew experimental method was developed to measure air-water interfacial area as a function of capillary pressure and water saturation in unsaturated porous media. The surfactant sodium dodecyl benzene sulfonate (SDBS) was used in equilibrium column adsorption experiments to determine the airwater interfacial area for water saturations (ml water/ml pore space) ranging from 0.05 to 1.0, and pressures ranging from 0 to 20 cm of water. A comparison was made between columns which were equilibrated under gravity drainage, versus columns equilibrated under secondary imbibition. Gravity drainage experiments showed the air-water interfacial area decreased linearly with saturation, while imbibition experiments showed a more complex non-monotonic relation to the saturation.
Gautier Y, Blunt MJ, Christie MA, 1999, Nested gridding and streamline-based simulation for fast reservoir performance prediction, Pages: 403-412
Detailed reservoir models routinely contain hundred of thousands to several million grid blocks. These models often cannot be used directly in a reservoir simulation because of the time and memory required for solving the pressure grid on the fine grid. We propose a nested gridding technique that efficiently obtains an approximate solution for the pressure field. The domain is divided into a series of coarse blocks, each containing many fine cells, for which effective mobilities are computed. The pressure is then found on the coarse scale. The pressure field within each coarse block is computed using constant flux boundary conditions obtained from the coarse pressure solution. In this way, a continuous but approximate velocity field is computed on the fine grid. The method is similar to the first step in a multigrid pressure solution. Streamline-based simulation is used to move saturations forward in time. The pressure field is periodically recomputed, taking account of the fine scale permeability and saturation distributions. We test the method for a series of example waterflood problems and demonstrate that the method can give accurate estimates of oil production for large 3D models up to 8.5 times faster than direct simulation using streamlines on the fine grid, making the method overall approximately up to 1,000 times faster than direct conventional simulation. The method is thus able to handle multi-million grid blocks problems easily, enabling simulation to be performed directly on detailed geological models. It is a robust alternative to traditional upscaling, since the effects of changing boundary conditions are automatically accommodated.
Schaefer CE, Roberts PV, Blunt MJ, 1999, Measurement and Prediction of Effective Diffusivities through Spreading and Nonspreading Oils in Unsaturated Porous Media, Environmental Science and Technology, Vol: 33, Pages: 2879-2884
Keller AA, Roberts PV, Blunt MJ, 1999, Effect of Fracture Aperture Variations on the Dispersion of Contaminants, Water Resources Research, Vol: 35, Pages: 55-63
Hughes RG, Blunt MJ, 1999, Pore-Scale Modeling of Multiphase Flow in Fractures and Matrix/Fracture Transfer, SPE Annual Conference and Exhibition, Houston, October
Gautier Y, Blunt MJ, Christie MA, 1999, Nested gridding and streamline-based simulation for fast reservoir performance prediction, COMPUTATIONAL GEOSCIENCES, Vol: 3, Pages: 295-320, ISSN: 1420-0597
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- Citations: 49
Firincioglu T, Blunt MJ, Zhou D, 1999, Three-Phase Flow and Wettability Effects in Triangular Capillaries, Colloids and Surfaces A, Vol: 155, Pages: 259-276
Fenwick DH, Blunt MJ, 1998, Network modeling of three-phase flow in porous media, SPE Journal, Vol: 3, ISSN: 1086-055X
We present a network model of three-phase flow in water-wet porous media. To explain the high oil recoveries in gas injection and gravity drainage experiments, we show that the mechanism for oil recovery is flow through connected oil layers in the pore space that are on the order of a micron thick. We then describe a simple model for the configuration of oil, water, and gas in a single pore and present an approximate expression for the conductance of oil layers. We use this expression to derive the oil relative permeability when flow is dominated by layer drainage. We show that for low oil and water saturations kro approx. So2, consistent with the results of several experiments. To predict kro for the full range of oil saturation we use a capillary equilibrium-based network model that can simulate any sequence of oil, water, and gas injection. We introduce a self-consistency procedure to ensure that the correct sequence of saturation changes is used in the network model to compute relative permeability. We then present relative permeabilities and oil recoveries for gas injection into different initial oil saturations, and for waterflooding a reservoir containing gas and oil. We show that the relative permeabilities are strongly affected by the fluid properties and by the type of displacement process.
Fenwick DH, Blunt MJ, 1998, Three-dimensional modeling of three phase imbibition and drainage, ADVANCES IN WATER RESOURCES, Vol: 21, Pages: 121-143, ISSN: 0309-1708
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- Citations: 161
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