Transport in Porous Media最新文献

{"title":"New Sub-grid Model for Convective Mixing in Field-Scale ({textrm{CO}}_2) Storage Simulation","authors":"Trine S. Mykkeltvedt,&nbsp;Tor Harald Sandve,&nbsp;Sarah E. Gasda","doi":"10.1007/s11242-024-02141-5","DOIUrl":"10.1007/s11242-024-02141-5","url":null,"abstract":"<div><p>Solubility trapping involves dissolution of supercritical carbon dioxide (CO<span>(_text {2})</span>) into the resident brine and is considered an important trapping mechanism for any Carbon Capture and Storage (CCS) project. Previous experimental and numerical studies indicate that density-driven convective mixing can greatly enhance solubility trapping, and is thus a key mechanism to capture when assessing the capacity of industry-scale CCS projects. However, convective mixing is a centimeter-scale phenomenon that is computationally challenging to resolve in standard reservoir simulation that uses coarse grid blocks. Therefore, the goal of this work is to incorporate convective mixing as a sub-grid effect within the traditional formulation of slightly miscible two-phase flow. We do this by adapting the classical model applied in individual grid cells to account for the transient behavior of the underlying convection and the downward transport of dissolved CO<span>(_text {2})</span>through the cell. The new sub-grid model for convective mixing is a mechanistic formulation based on observations from high-resolution simulations. The model employs a set of non-dimensional parameters, calibrated against 2D simulations that allow it to be applied generally to any reservoir properties. We show that the calibrated sub-grid model is easily implemented in a 3D reservoir simulator and benchmark it against a fully resolved field-scale simulation of CO<span>(_text {2})</span>injection in a sloping aquifer. The sub-grid model shows a marked improvement in computing the total amount of CO<span>(_text {2})</span>dissolved over time compared with the classical model for the tested cases. The new implementation is further applied to the openly available model for the Smeaheia storage site in the Norwegian North Sea, to demonstrate the utility of the new model to improve estimates of CO<span>(_text {2})</span>dissolution and explore parameter sensitivities for realistic storage projects.</p></div>","PeriodicalId":804,"journal":{"name":"Transport in Porous Media","volume":"152 1","pages":""},"PeriodicalIF":2.7,"publicationDate":"2024-12-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://link.springer.com/content/pdf/10.1007/s11242-024-02141-5.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142859811","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Uncertainty Quantification on Foam Modeling: The Interplay of Relative Permeability and Implicit-texture Foam Parameters","authors":"G. B. de Miranda,&nbsp;R. W. dos Santos,&nbsp;G. Chapiro,&nbsp;B. M. Rocha","doi":"10.1007/s11242-024-02137-1","DOIUrl":"10.1007/s11242-024-02137-1","url":null,"abstract":"<div><p>Efficient decision-making in foam-assisted applications, such as soil remediation and enhanced oil recovery, frequently relies on intricate models that are developed based on a selection of component models that describe the underlying physics of the phenomenon at hand. Modeling foam flow is challenging due to the complex interactions between foam properties, porous media characteristics, and flow dynamics, which results in significant uncertainties in model predictions. Previous studies on uncertainty in foam flow models have only analyzed foam properties and relative permeability separately, leading to limited reliability of the findings. This study aims to bridge the gap of integrating foam implicit-texture parametrization and relative permeability into an uncertainty quantification (UQ) framework to evaluate multi-phase foam flow simulations in porous media more comprehensively than previously available. A foam representation based on the CMG-STARS and a Corey relative permeability model are employed. Bayesian techniques and polynomial chaos expansion (PCE) are employed for inverse and forward UQ. These techniques enable the quantification of uncertainties and the identification of influential parameters within the model. An initial guess algorithm to represent prior beliefs objectively is introduced for the inverse uncertainty quantification step. An in-house foam displacement simulator, aided by a surrogate model, is employed in forward uncertainty quantification and sensitivity analysis. The research findings contribute to understanding and designing reliable foam flow simulations. Sensitivity analyses indicate that incremental strategies to fit parameters can produce inaccurate predictions. Additionally, the article discusses how inaccurately estimated parameters can lead to underestimation or overestimation of foam performance in simulations.</p></div>","PeriodicalId":804,"journal":{"name":"Transport in Porous Media","volume":"152 1","pages":""},"PeriodicalIF":2.7,"publicationDate":"2024-12-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142826167","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Multimodality Imaging of Fluid Saturation and Chemical Transport for Two-Phase Surfactant/Polymer Floods in Porous Rocks","authors":"Andrea Rovelli,&nbsp;James Brodie,&nbsp;Bilal Rashid,&nbsp;Weparn J. Tay,&nbsp;Ronny Pini","doi":"10.1007/s11242-024-02146-0","DOIUrl":"10.1007/s11242-024-02146-0","url":null,"abstract":"<div><p>Multicomponent, two-phase flow in porous media is a problem of practical relevance that remains difficult to study experimentally. Advanced methodologies are needed that enable the monitoring of both the saturation of each fluid phase within the pore space and the concentration of the chemical species within the fluids. We present an approach based on multimodality imaging and apply it to the case study of surfactant/polymer flooding in a sandstone for enhanced oil recovery. X-ray computed tomography and positron emission tomography (PET) are applied for the asynchronous acquisition of dynamic profiles of saturations (aqueous and oleic) and of the solute concentration within the surfactant/polymer slug, respectively. This complementary dataset enables precise investigation of the evolution of both the oil bank and the induced mixing at its rear arising from the surfactant/polymer flooding process. The dilution index, intensity of segregation and the spreading length are used to quantify the degree of mixing within the surfactant/polymer slug as a function of time from the spatial structure of the solute concentration field. Relative to the single-phase flow scenario, a threefold increase in dispersivity is observed. We demonstrate that mixing is systematically overestimated if only the PET dataset is used—highlighting the importance of implementing multimodality imaging. We also show that the advection–dispersion equation model, parameterised using the dispersivity derived from the experiments, provides reasonable estimates for the rate of both mixing and spreading.</p></div>","PeriodicalId":804,"journal":{"name":"Transport in Porous Media","volume":"152 1","pages":""},"PeriodicalIF":2.7,"publicationDate":"2024-12-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://link.springer.com/content/pdf/10.1007/s11242-024-02146-0.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142810881","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A Unified Method for the Mobility Prediction of an Inelastic Non-Newtonian Fluid Through Complex Porous Media","authors":"Hye Kyeong Jang,&nbsp;Youngseok Oh,&nbsp;Wook Ryol Hwang","doi":"10.1007/s11242-024-02145-1","DOIUrl":"10.1007/s11242-024-02145-1","url":null,"abstract":"<div><p>In this work, we propose a novel method to quantify flows of inelastic non-Newtonian fluids in porous media based on the energy dissipation rate. Unlike the permeability of a Newtonian fluid with Darcy’s law, the permeability of a non-Newtonian fluid shows complicated behaviors due to non-separable effects of the geometry and rheology. We suggest a simple energy dissipation-based flow characterization method to resolve this problem, employing the concepts of effective viscosity and effective shear rate. These effective quantities can be defined with two flow numbers (the energy dissipation rate coefficient and the effective shear rate coefficient) independent of fluid rheology. New expressions for the permeability of Newtonian and mobility of non-Newtonian fluids were derived for model porous media in this approach. We show that the mobility (a ratio of permeability to viscosity) of a non-Newtonian fluid for a given porous media can be factored into the permeability of Newtonian fluid and the effective viscosity, exactly the same as in case of a Newtonian fluid. The proposed quantification method was validated through example problems of flows using numerical simulations (1) in two-dimensional (2D) transverse fibrous porous media (quadratic and hexagonal), (2) flows in three-dimensional (3D) regularly packed beds with spheres (faced-centered cubic and body-centered cubic), and (3) finally randomly distributed unidirectional fibers in 2D. The suggested method can quantitatively assess tortuous path in porous electrode for electrolyte transport and in the secondary oil recovery, offering the potential to optimize performance and efficiency in these applications.</p></div>","PeriodicalId":804,"journal":{"name":"Transport in Porous Media","volume":"152 1","pages":""},"PeriodicalIF":2.7,"publicationDate":"2024-12-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142798490","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Water and Oil Volume Measurement Using UV–Visible Spectroscopy","authors":"Mohammad Sarlak,&nbsp;Jules Reed,&nbsp;Stuart Law,&nbsp;Alan J. McCue,&nbsp;Yukie Tanino","doi":"10.1007/s11242-024-02140-6","DOIUrl":"10.1007/s11242-024-02140-6","url":null,"abstract":"<p>Fluid saturation in relative permeability experiments is typically determined by volumetric or gravimetric measurements, as well as in-situ saturation monitoring (ISSM). Gravimetric measurements tend to have larger error due to grain loss. The conventional volumetric method used can be a challenge because produced volumes for oil and water must be separated and measured manually. ISSM method is also a costly technique. In this study, an UV–visible spectroscopy was used to continuously and cost effectively measure oil and water volumes. A water-oil unsteady state relative permeability was performed to investigate the feasibility of calculating oil and water volumes using UV–visible spectroscopy. UV–visible spectroscopy is a quantitative technique in analytical chemistry to determine concentrations of known solutes. A UV–visible spectroscope was located in the flow line immediately after the core holder and used to quantify fluid volumes (oil and water) produced from a core sample during unsteady state relative permeability study. A volumetric separator was also used to compare production volumes obtained from UV–visible spectroscope. The relative permeabilities were calculated using JBN method from both volumetric and UV-visible spectroscope measurements and then history matched with Sendra (PRORES AS). The final oil volume produced, oil and water relative permeability curves obtained from UV–visible spectroscope measurements were in good agreement with volumetric measurements. The Corey relative permeability curves simulated from Sendra also were closely matched with analytical relative permeability curves obtained using volume measurements from volumetric and UV–visible spectroscope data. Nuclear Magnetic Resonance (NMR) on post relative permeability experiment was also in good agreement with UV–visible spectroscope measurement. UV–visible spectroscopy was also used to measure the breakthrough time of the injected fluid. Breakthrough time estimated using in-line UV–visible spectrophotometer was 0.634 PVI compared to 0.617 and 0.673 PVI from pressure data and volumetric observations.</p>","PeriodicalId":804,"journal":{"name":"Transport in Porous Media","volume":"152 1","pages":""},"PeriodicalIF":2.7,"publicationDate":"2024-12-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://link.springer.com/content/pdf/10.1007/s11242-024-02140-6.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142798453","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Pressure Drop and Interfacial Heat Transfer Coefficient Formulation for Packed Bed Systems with Cylindrical Capsules","authors":"Akshay Kumar,&nbsp;Pratyush Kumar,&nbsp;Sandip K. Saha","doi":"10.1007/s11242-024-02143-3","DOIUrl":"10.1007/s11242-024-02143-3","url":null,"abstract":"<div><p>Packed beds with cylindrical particles of polymeric material are a better option for developing low-cost, durable thermal energy storage for higher temperature ranges and corrosive environments. In this work, the formulations for pressure drop and interfacial convective heat transfer coefficient in the packed bed system (PBS) filled with cylindrical particles are developed for a wide range of geometrical and operating parameters. Two experimental setups are developed to determine the effects of superficial velocity, porosity of PBS, and geometrical dimensions of cylindrical particles on pressure drop and interfacial convective heat transfer coefficient. A discrete element method-based numerical model of PBS is developed to obtain the effect of fluid properties. The machine learning regression is deployed on the experimental and numerical data set to obtain a pressure drop formulation. Further, an analytical expression based on the Ergun equation is developed to approximate the machine-learning-based pressure drop formulation. The interfacial heat transfer coefficient is estimated by solving the steady-state heat conduction equation using the experimentally measured particle surface and air temperatures. The developed pressure drop and interfacial heat transfer coefficient formulations show maximum mean absolute deviations of less than 10.1% and 5.5%, respectively, with the experimental results.</p><h3>Graphical Abstract</h3><div><figure><div><div><picture><source><img></source></picture></div></div></figure></div></div>","PeriodicalId":804,"journal":{"name":"Transport in Porous Media","volume":"152 1","pages":""},"PeriodicalIF":2.7,"publicationDate":"2024-12-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142789183","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Impact of Acid Strength and Mineral Composition on Spontaneous Imbibition with Reactive Fluids","authors":"Muhammad Andiva Pratama,&nbsp;Hasan Javed Khan","doi":"10.1007/s11242-024-02138-0","DOIUrl":"10.1007/s11242-024-02138-0","url":null,"abstract":"<div><p>Capillary rise experiments are conducted in a set of calcareous and siliceous rocks with varying mineralogy and petrophysical properties to understand the coupled impact of reactivity and spontaneous imbibition. A capillary rise experiment is performed in each sample: first with deionized water, then with a dilute acidic solution, and finally again with deionized water, and the capillary rise profile for each is recorded. Pre- and post-acid petrophysical properties such as porosity, permeability, pore size distribution, and contact angle are measured for each sample. The mineral makeup of the rocks significantly influences how the acidic fluids penetrate the samples. The primary reactions are the dissolution of Ca- and Mg-rich minerals which alter the pore network. The higher acid strength results in higher capillary rise in calcareous rocks and results in an increase in the average pore size. The same pH acid results in lower capillary rise in the siliceous rocks, and a general decrease in the average pore size is observed. Changes in contact angle indicate increased water affinity in carbonate and reduced affinity in sandstone. The link between capillary interactions and fluid reactivity is often overlooked in fluid flow studies, and this research sheds light on the importance of reactivity during spontaneous imbibition, offering insights into dissolution and precipitation processes during capillary flow.</p></div>","PeriodicalId":804,"journal":{"name":"Transport in Porous Media","volume":"152 1","pages":""},"PeriodicalIF":2.7,"publicationDate":"2024-12-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://link.springer.com/content/pdf/10.1007/s11242-024-02138-0.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142789182","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Characterization of Size-Dependent Inertial Permeability for Rough-Walled Fractures","authors":"Zihao Sun,&nbsp;Liangqing Wang,&nbsp;Liangchao Zou,&nbsp;Jia-Qing Zhou","doi":"10.1007/s11242-024-02139-z","DOIUrl":"10.1007/s11242-024-02139-z","url":null,"abstract":"<div><p>Inertial permeability is a critical parameter that quantifies the pressure loss caused by inertia in fluid flow through rough-walled fractures, described by the Forchheimer equation. This study investigates the size effect on the inertial permeability of rough-walled fractures and establishes a characterization model for fractures of varying sizes. Numerical simulations are conducted on five large-scale fracture models (1 m × 1 m) by resolving the Navier–Stokes equations. Smaller models are extracted from these large-scale fracture models for detailed size-dependent analysis. The results show that the peak asperity height (<i>ξ</i>), asperity height variation coefficient (<i>η</i>), and the fitting coefficient of the aperture cumulative distribution curve (<i>C</i>) significantly affect inertial permeability. Specifically, as <i>ξ</i> increases, the fluid flow experiences greater resistance, resulting in a reduction of inertial permeability. Similarly, a larger <i>η</i> corresponds to more variable asperity heights, further decreasing permeability. In contrast, a higher <i>C</i> value, indicating a more uniform aperture distribution, increases inertial permeability by facilitating smoother fluid flow. Quantitatively, the relationship between inertial permeability and fracture size follows a power law, with the sensitivity to roughness parameters diminishing as fracture size increases. This characterization model provides a method for scaling from laboratory-scale to field-scale fractures, offering practical implications for hydraulic engineering and subsurface fluid flow management.</p></div>","PeriodicalId":804,"journal":{"name":"Transport in Porous Media","volume":"152 1","pages":""},"PeriodicalIF":2.7,"publicationDate":"2024-12-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142778532","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"An Integrated Model with Reconstructed Full-Scale Shale Matrix and Fractures","authors":"Jingchun Feng,&nbsp;Qingrong Xiong,&nbsp;Diansen Yang","doi":"10.1007/s11242-024-02144-2","DOIUrl":"10.1007/s11242-024-02144-2","url":null,"abstract":"<div><p>Four types of voids exist in shale, including inorganic pores, organic pores, natural fractures, and hydraulic fractures, where the gas flow within is affected by voids sizes, shapes, and the mineral composition surrounding them. It is still a challenge to build an effective multi-scale model for shale by now. A model classifying organic pores and inorganic pores with and without clay was proposed in our previous work by incorporating various testing methods. However, some improvements can be made, including wider the pore size of the model to full-scale and adding the fractures without being considered previously. Therefore, a new model is proposed by integrating an improved full-scale matrix pore network model (PNM) with fractures. That is, the effects of four types of voids, including organic pores, inorganic pores containing clay, inorganic pores without clay, and fractures, on gas flow are all considered in the model. Then, the factors affecting the permeability of the matrix (i.e., without fractures) and the whole model (i.e., with fractures) were analyzed. The results show that connectivity both in small- and large-scale PNM and total organic content facilitate the flow, while clay content and water film thickness hinder the flow, especially within small pores. Fractures along the pressure drop accelerate gas flow, and the fractures perpendicular to the pressure drop only channel the pressure when the fractures along the pressure drop both exist. The model can be applied to other mudstones and shales and studies the fluid migration within them through proper parameters adjustment.</p></div>","PeriodicalId":804,"journal":{"name":"Transport in Porous Media","volume":"152 1","pages":""},"PeriodicalIF":2.7,"publicationDate":"2024-12-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142761976","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"On the Viscous Crossflow During the Foam Displacement in Two-Layered Porous Media","authors":"A. J. Castrillón Vásquez,&nbsp;P. Z. S. Paz,&nbsp;G. Chapiro","doi":"10.1007/s11242-024-02135-3","DOIUrl":"10.1007/s11242-024-02135-3","url":null,"abstract":"<div><p>Foam flow in porous media increased the scientific community’s attention due to several potential industrial applications, including remediation of contaminated aquifers, soil remediation, acid diversion, and hydrocarbon recovery. Natural reservoirs typically have fractured and multi-layered structures. We investigate an immiscible incompressible two-phase foam flow in an internally homogeneous two-layered porous medium with different porosities and absolute permeabilities. For our analysis, we extended the previous result, evidencing that the presence of foam induces the existence of a single flow front in both layers. Using the traveling wave solution, we classify the foam flow depending on the absolute permeability and the porosity ratio between layers. We show that the mass crossflow between layers is connected to the relative position of the flow front in these layers and that the porosity difference between layers impacts the mass crossflow. All analytical estimates were supported by direct numerical simulations.</p></div>","PeriodicalId":804,"journal":{"name":"Transport in Porous Media","volume":"151 15","pages":"2835 - 2857"},"PeriodicalIF":2.7,"publicationDate":"2024-11-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142679600","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":3,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}