The Experts below are selected from a list of 279 Experts worldwide ranked by ideXlab platform
Sally M. Benson - One of the best experts on this subject based on the ideXlab platform.
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Capillary Pressure heterogeneity and hysteresis for the supercritical co2 water system in a sandstone
Advances in Water Resources, 2017Co-Authors: Ronny Pini, Sally M. BensonAbstract:We report results from an experimental investigation on the hysteretic behaviour of the Capillary Pressure Curve for the supercritical CO2-water system in a Berea Sandstone core. Previous observations have highlighted the importance of subcore-scale Capillary heterogeneity in developing local saturations during drainage; we show in this study that the same is true for the imbibition process. Spatially distributed drainage and imbibition scanning Curves were obtained for mm-scale subsets of the rock sample non-invasively using X-ray CT imagery. Core- and subcore-scale measurements are well described using the Brooks–Corey formalism, which uses a linear trapping model to compute mobile saturations during imbibition. Capillary scaling yields two separate universal drainage and imbibition Curves that are representative of the full subcore-scale data set. This enables accurate parameterisation of rock properties at the subcore-scale in terms of Capillary scaling factors and permeability, which in turn serve as effective indicators of heterogeneity at the same scale even when hysteresis is a factor. As such, the proposed core-analysis workflow is quite general and provides the required information to populate numerical models that can be used to extend core-flooding experiments to conditions prevalent in the subsurface, which would be otherwise not attainable in the laboratory.
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Extraction of pore-morphology and Capillary Pressure Curves of porous media from synchrotron-based tomography data
Scientific reports, 2015Co-Authors: Feifei Yang, Ferdinand F. Hingerl, Xianghui Xiao, Yijin Liu, Sally M. Benson, Michael F. ToneyAbstract:The elevated level of atmospheric carbon dioxide (CO2) has caused serious concern of the progression of global warming. Geological sequestration is considered as one of the most promising techniques for mitigating the damaging effect of global climate change. Investigations over wide range of length-scales are important for systematic evaluation of the underground formations from prospective CO2 reservoir. Understanding the relationship between the micro morphology and the observed macro phenomena is even more crucial. Here we show Synchrotron based X-ray micro tomographic study of the morphological buildup of Sandstones. We present a numerical method to extract the pore sizes distribution of the porous structure directly, without approximation or complex calculation. We have also demonstrated its capability in predicting the Capillary Pressure Curve in a mercury intrusion porosimetry (MIP) measurement. The method presented in this work can be directly applied to the morphological studies of heterogeneous systems in various research fields, ranging from Carbon Capture and Storage, and Enhanced Oil Recovery to environmental remediation in the vadose zone.
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Capillary heterogeneity in sandstone rocks during co2 water core flooding experiments
Energy Procedia, 2013Co-Authors: Ronny Pini, Samuel Krevor, Michael Krause, Sally M. BensonAbstract:Abstract We have successfully applied a novel experimental technique to measure drainage Capillary Pressure Curves in reservoir rocks with representative reservoir fluids at high temperatures and Pressures. The method consists of carrying out 100% CO 2 flooding experiments at increasingly higher flow rates on a core that is initially saturated with water and requires that the wetting-phase Pressure is continuous across the outlet face of the sample. Experiments have been carried out on a Berea Sandstone core at 25 and 50 °C and at 9 MPa pore Pressure, while keeping the confining Pressure at 12 MPa. Measurements are in good agreement with data from mercury intrusion porosimetry. The technique possesses a great potential of applicability due to the following reasons: (a) it can be applied in conjunction with steady-state relative permeability measurements, as it shares a very similar experimental configuration; (b) it is faster than traditional (porous-plate) techniques used for measuring Capillary Pressure on rock cores with reservoir fluids; (c) by comparison with results from mercury porosimetry, it allows for the estimation of the interfacial and wetting properties of the CO 2 /water system, the latter being unknown for most rocks; (d) by combination with X-ray CT scanning, the method allows for the observation of Capillary Pressure–saturation relationships on mm-scale subsets of the rock core. The latter are of high relevance as they directly and non- destructively measure Capillary Pressure Curve heterogeneity in sandstone rocks.
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Influence of Capillary-Pressure models on CO2 solubility trapping
Advances in Water Resources, 2013Co-Authors: Hamdi A. Tchelepi, Sally M. Benson, Sally M. Benson, Sally M. BensonAbstract:Abstract The typical shape of a Capillary-Pressure Curve is either convex (e.g., Brooks–Corey model) or S-shaped (e.g., van Genuchten model). It is not universally agreed which model reflects natural rocks better. The difference between the two models lies in the representation of the Capillary entry Pressure. This difference does not lead to significantly different simulation results for modeling CO2 sequestration in aquifers without considering CO2 dissolution. However, we observe that the van-Genuchten-type Capillary-Pressure model accelerates CO2 solubility trapping significantly compared with the Brooks–Corey-type model. We also show that the simulation results are very sensitive to the slope of the van-Genuchten-type Curve around the entry-Pressure region. For the representative examples we study, the differences can be so large as to have complete dissolution of the CO2 plume versus persistence of over 50% of the plume over a 5000-year period. The cause of such sensitivity to the Capillary-Pressure model is studied. Particularly, we focus on how the entry Pressure is represented in each model. We examine the mass-transfer processes under gravity-Capillary equilibrium, molecular diffusion, convective mixing, and in the presence of small-scale heterogeneities. Laboratory measurement of Capillary-Pressure Curves and some important implementation issues of Capillary-Pressure models in numerical simulators are also discussed. Most CO2 sequestration simulations in the literature employ one of the two Capillary-Pressure models. It is important to recognize that these two representations lead to very different predictions of long-term CO2 sequestration.
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Capillary Pressure and heterogeneity for the co2 water system in sandstone rocks at reservoir conditions
Advances in Water Resources, 2012Co-Authors: Ronny Pini, Samuel Krevor, Sally M. BensonAbstract:Abstract A novel method is presented to measure drainage Capillary Pressure Curves both at the core and sub-core scale using CO2 and water at reservoir conditions. The experimental configuration is very similar to the one used in traditional steady-state relative permeability experiments. Capillary Pressure measurements are made at the inlet face of the sample by successively increasing the flow rate of the non-wetting phase while measuring the saturation with a medical X-ray Computed Tomography (CT) scanner. The method requires that the wetting phase Pressure is uniform across the core and can be measured in the outlet end-cap. A Capillary Pressure Curve is obtained in less than two days, as compared to weeks for existing methods that use porous plates. Drainage Capillary Pressure Curves of CO2 and water are measured for two sandstones rock cores with different lithology and pore size distribution. Experiments are carried out at 25 and 50 °C and at 9 MPa pore Pressure, while keeping the confining Pressure on the core at 12 MPa. There is excellent agreement between the new method and data from mercury intrusion porosimetry; beside providing confidence in the new technique, such comparison allows for an estimate of the wetting and interfacial properties of the CO2/water system. X-ray CT scanning allows for precise imaging of fluid saturations at a resolution of about (2.5 × 2.5 × 1) mm3, thus enabling quantification of sub-core scale Capillary Pressure Curves. These measurements provide independent confirmation that sub-core scale Capillary heterogeneity plays an important role in controlling saturation distributions during multiphase flow.
Ronny Pini - One of the best experts on this subject based on the ideXlab platform.
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Capillary Pressure heterogeneity and hysteresis for the supercritical co2 water system in a sandstone
Advances in Water Resources, 2017Co-Authors: Ronny Pini, Sally M. BensonAbstract:We report results from an experimental investigation on the hysteretic behaviour of the Capillary Pressure Curve for the supercritical CO2-water system in a Berea Sandstone core. Previous observations have highlighted the importance of subcore-scale Capillary heterogeneity in developing local saturations during drainage; we show in this study that the same is true for the imbibition process. Spatially distributed drainage and imbibition scanning Curves were obtained for mm-scale subsets of the rock sample non-invasively using X-ray CT imagery. Core- and subcore-scale measurements are well described using the Brooks–Corey formalism, which uses a linear trapping model to compute mobile saturations during imbibition. Capillary scaling yields two separate universal drainage and imbibition Curves that are representative of the full subcore-scale data set. This enables accurate parameterisation of rock properties at the subcore-scale in terms of Capillary scaling factors and permeability, which in turn serve as effective indicators of heterogeneity at the same scale even when hysteresis is a factor. As such, the proposed core-analysis workflow is quite general and provides the required information to populate numerical models that can be used to extend core-flooding experiments to conditions prevalent in the subsurface, which would be otherwise not attainable in the laboratory.
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Capillary heterogeneity in sandstone rocks during co2 water core flooding experiments
Energy Procedia, 2013Co-Authors: Ronny Pini, Samuel Krevor, Michael Krause, Sally M. BensonAbstract:Abstract We have successfully applied a novel experimental technique to measure drainage Capillary Pressure Curves in reservoir rocks with representative reservoir fluids at high temperatures and Pressures. The method consists of carrying out 100% CO 2 flooding experiments at increasingly higher flow rates on a core that is initially saturated with water and requires that the wetting-phase Pressure is continuous across the outlet face of the sample. Experiments have been carried out on a Berea Sandstone core at 25 and 50 °C and at 9 MPa pore Pressure, while keeping the confining Pressure at 12 MPa. Measurements are in good agreement with data from mercury intrusion porosimetry. The technique possesses a great potential of applicability due to the following reasons: (a) it can be applied in conjunction with steady-state relative permeability measurements, as it shares a very similar experimental configuration; (b) it is faster than traditional (porous-plate) techniques used for measuring Capillary Pressure on rock cores with reservoir fluids; (c) by comparison with results from mercury porosimetry, it allows for the estimation of the interfacial and wetting properties of the CO 2 /water system, the latter being unknown for most rocks; (d) by combination with X-ray CT scanning, the method allows for the observation of Capillary Pressure–saturation relationships on mm-scale subsets of the rock core. The latter are of high relevance as they directly and non- destructively measure Capillary Pressure Curve heterogeneity in sandstone rocks.
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Capillary Pressure and heterogeneity for the co2 water system in sandstone rocks at reservoir conditions
Advances in Water Resources, 2012Co-Authors: Ronny Pini, Samuel Krevor, Sally M. BensonAbstract:Abstract A novel method is presented to measure drainage Capillary Pressure Curves both at the core and sub-core scale using CO2 and water at reservoir conditions. The experimental configuration is very similar to the one used in traditional steady-state relative permeability experiments. Capillary Pressure measurements are made at the inlet face of the sample by successively increasing the flow rate of the non-wetting phase while measuring the saturation with a medical X-ray Computed Tomography (CT) scanner. The method requires that the wetting phase Pressure is uniform across the core and can be measured in the outlet end-cap. A Capillary Pressure Curve is obtained in less than two days, as compared to weeks for existing methods that use porous plates. Drainage Capillary Pressure Curves of CO2 and water are measured for two sandstones rock cores with different lithology and pore size distribution. Experiments are carried out at 25 and 50 °C and at 9 MPa pore Pressure, while keeping the confining Pressure on the core at 12 MPa. There is excellent agreement between the new method and data from mercury intrusion porosimetry; beside providing confidence in the new technique, such comparison allows for an estimate of the wetting and interfacial properties of the CO2/water system. X-ray CT scanning allows for precise imaging of fluid saturations at a resolution of about (2.5 × 2.5 × 1) mm3, thus enabling quantification of sub-core scale Capillary Pressure Curves. These measurements provide independent confirmation that sub-core scale Capillary heterogeneity plays an important role in controlling saturation distributions during multiphase flow.
Liqiang Sima - One of the best experts on this subject based on the ideXlab platform.
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predicting gas water relative permeability using nuclear magnetic resonance and mercury injection Capillary Pressure measurements
Journal of Natural Gas Science and Engineering, 2016Co-Authors: Qicheng Fan, Dan Huang, Xiaoyu Liang, Liqiang SimaAbstract:Abstract Relative permeability functions are useful in understanding gas–water two–phase flow in rocks and reservoirs. When direct laboratory data of relative permeability are not available for evaluating gas-water two-phase flow in rocks and reservoirs, indirect prediction models using gas-water relative permeability functions are widely used. In this research, four typical existing predicting models of relative permeability based on Capillary Pressure are investigated (the Purcell, Burdine, Brooks–Corey and Li models). These models notably simplify the gas–water spatial distribution in rocks: the Purcell, Burdine and Brooks–Corey models all assume that gas flows in large tubes, while water flows in small tubes, and irreducible water adsorbed on tube surfaces is not considered. Alternatively, the Li model considers irreducible water adsorbed on tube surface; however, the proportion of irreducible water, mobile water and gas are assumed to be constant in tubes with different radii, as this model was derived from a single tube flow structure. This research proposes a new relative permeability model in which the pore–size distribution, the tortuosity and the gas–water spatial distribution are all considered. A bundle of Capillary tubes model and modified single-tube flow model are applied in the proposed model. Capillary tubes in the rock are divided into large tubes and small tubes. In large tubes, the water phase contacts the tube surface and is partially adsorbed onto the surface and partially mobile, while gas phase flows in the center of tubes and is surrounded by water. In small tubes, only irreducible water exists. Variables in the proposed model such as the thickness of irreducible water, mobile water and gas are usually unknown. Combined with a Capillary Pressure Curve, the shift of the transversal time (T2) distribution of Nuclear Magnetic Resonance is used to determine these variables. The proposed model is validated by experimental data from six rock samples that have different lithology, diagenesis characteristics, pore structure characteristics, irreducible water saturation and different grades of T2 distribution shifts. The model results are compared with the calculated values from other four existing models and the experimental data. Our results show that the proposed model matches the experimental data better than other models, and diagenesis and pore structure characteristics are more sensitive to the proposed model than is lithology.
Samuel Krevor - One of the best experts on this subject based on the ideXlab platform.
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Capillary heterogeneity in sandstone rocks during co2 water core flooding experiments
Energy Procedia, 2013Co-Authors: Ronny Pini, Samuel Krevor, Michael Krause, Sally M. BensonAbstract:Abstract We have successfully applied a novel experimental technique to measure drainage Capillary Pressure Curves in reservoir rocks with representative reservoir fluids at high temperatures and Pressures. The method consists of carrying out 100% CO 2 flooding experiments at increasingly higher flow rates on a core that is initially saturated with water and requires that the wetting-phase Pressure is continuous across the outlet face of the sample. Experiments have been carried out on a Berea Sandstone core at 25 and 50 °C and at 9 MPa pore Pressure, while keeping the confining Pressure at 12 MPa. Measurements are in good agreement with data from mercury intrusion porosimetry. The technique possesses a great potential of applicability due to the following reasons: (a) it can be applied in conjunction with steady-state relative permeability measurements, as it shares a very similar experimental configuration; (b) it is faster than traditional (porous-plate) techniques used for measuring Capillary Pressure on rock cores with reservoir fluids; (c) by comparison with results from mercury porosimetry, it allows for the estimation of the interfacial and wetting properties of the CO 2 /water system, the latter being unknown for most rocks; (d) by combination with X-ray CT scanning, the method allows for the observation of Capillary Pressure–saturation relationships on mm-scale subsets of the rock core. The latter are of high relevance as they directly and non- destructively measure Capillary Pressure Curve heterogeneity in sandstone rocks.
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Capillary Pressure and heterogeneity for the co2 water system in sandstone rocks at reservoir conditions
Advances in Water Resources, 2012Co-Authors: Ronny Pini, Samuel Krevor, Sally M. BensonAbstract:Abstract A novel method is presented to measure drainage Capillary Pressure Curves both at the core and sub-core scale using CO2 and water at reservoir conditions. The experimental configuration is very similar to the one used in traditional steady-state relative permeability experiments. Capillary Pressure measurements are made at the inlet face of the sample by successively increasing the flow rate of the non-wetting phase while measuring the saturation with a medical X-ray Computed Tomography (CT) scanner. The method requires that the wetting phase Pressure is uniform across the core and can be measured in the outlet end-cap. A Capillary Pressure Curve is obtained in less than two days, as compared to weeks for existing methods that use porous plates. Drainage Capillary Pressure Curves of CO2 and water are measured for two sandstones rock cores with different lithology and pore size distribution. Experiments are carried out at 25 and 50 °C and at 9 MPa pore Pressure, while keeping the confining Pressure on the core at 12 MPa. There is excellent agreement between the new method and data from mercury intrusion porosimetry; beside providing confidence in the new technique, such comparison allows for an estimate of the wetting and interfacial properties of the CO2/water system. X-ray CT scanning allows for precise imaging of fluid saturations at a resolution of about (2.5 × 2.5 × 1) mm3, thus enabling quantification of sub-core scale Capillary Pressure Curves. These measurements provide independent confirmation that sub-core scale Capillary heterogeneity plays an important role in controlling saturation distributions during multiphase flow.
Weibiao Xie - One of the best experts on this subject based on the ideXlab platform.
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variable dimension fractal based conversion method between the nuclear magnetic resonance t2 spectrum and Capillary Pressure Curve
Energy & Fuels, 2021Co-Authors: Weibiao Xie, Qiuli Yin, Guiwen WangAbstract:Pore structure is the primary control factor of pore fluid distribution and flow capacity. It is an important content in reservoir evaluation. The Capillary Pressure Curve is a major method to obta...
