Abstract: In accordance with one or more embodiments of the present disclosure, a low-density treatment fluid includes a base water-control system and at least one light-weight filler material. The base water-control system may include an inorganic material system comprising an aqueous colloidal silica and a water-soluble chemical activator for gelling the colloidal silica, or the base water-control system may include an organic material system comprising of polymeric material. The low-density treatment fluid may have a density of from 0.1 g/cm3 to 0.75 g/cm3. Also described are methods of recovering a target fluid from a subterranean cavity using such a low-density treatment fluid.

Abstract: A workflow for rock sample image processing is established to determine geometrical parameters of rock texture. Individual pores and grains are identified using Hoshen-Kopelman multi-cluster labeling algorithm and watershedding technique. Separated elements are fitted with ellipses and pore/grain size distributions, aspect ratios and orientations of fitting ellipses are obtained. Such information is especially valuable in interpretation and forward modeling of dielectric responses using textural models. Rock sample images by high-resolution confocal microscopy are selected to test the workflow and results are analyzed.

Abstract: A workflow for rock sample image processing is established to determine geometrical parameters of rock texture. Individual pores and grains are identified using Hoshen-Kopelman multi-cluster labeling algorithm and watershedding technique. Separated elements are fitted with ellipses and pore/grain size distributions, aspect ratios and orientations of fitting ellipses are obtained. Such information is especially valuable in interpretation and forward modeling of dielectric responses using textural models. Rock sample images by high-resolution confocal microscopy are selected to test the workflow and results are analyzed.

Abstract: Materials and methods for protecting electric cables and connectors from corrosive atmospheres and chemicals, particularly in oil wells, are provided herein.

Abstract: Methods for upscaling digital rock modeling data are described. Core-plug samples for pore-scale modeling are chosen using whole-core mini-permeability grids and conventional CT scans. Pore models or pore-network models are used for flow modeling. Borehole-scale models use MPS (Multi-Point Statistics) to combine mini-permeability grids and conventional CTscans of whole core with electrical borehole images to create 3D numerical pseudocores for each RRT (Reservoir Rock Type). Effective SCAL properties computed from various MPS borehole-scale realizations or models are used to populate interwell-scale models for each RRT. Effective properties computed from flow simulations for interwell volumes are used to populate full-field scale models. At the full-field scale, outcrop analogs, sequence stratigraphy, forward stratigraphic models, diagenetic models, and basin-scale models are combined using MPS to improve flow simulations.

Abstract: In one embodiment, the current application discloses a method comprising: performing a computed tomography (CT) porosity scan on a core sample, the core sample comprising a portion of a formation of interest; in response to the CT porosity scan, interpreting a porosity profile of the core sample; and in response to the porosity profile, modeling a response of a formation of interest to a predetermined treatment to determine a reacted formation configuration, wherein the predetermined treatment comprises an acid fluid treatment schedule, and wherein the modeling further comprises modeling acid fluid flow through the formation of interest having the porosity profile, and wherein the modeling further comprises accounting for acid reaction products during the predetermined treatment and shut-in period.

Abstract: This disclosed subject matter is generally related to methods for characterizing two-dimensional (2D) and three-dimensional (3D) samples to determine pore-body and pore-throat size distributions and capillary pressure curves in porous media using petrographic image analysis. Input includes high-resolution petrographic images and laboratory-derived porosity measurements. Output includes: (1) pore-body and pore-throat size distributions, and (2) simulated capillary pressure curves for both pore bodies and pore throats.

Abstract: This subject disclosure describes methods to build and/or enhance 3D digital models of porous media by combining high- and low-resolution data to capture large and small pores in single models. High-resolution data includes laser scanning fluorescence microscopy (LSFM), nano computed tomography (CT) scans, and focused ion beam-scanning electron microscopy (FIB-SEM). Low-resolution data includes conventional CT scans, micro computed tomography scans, and synchrotron computed tomography scans.

Abstract: In one embodiment, the current application discloses a method comprising: performing a computed tomography (CT) porosity scan on a core sample, the core sample comprising a portion of a formation of interest; in response to the CT porosity scan, interpreting a porosity profile of the core sample; and in response to the porosity profile, modeling a response of a formation of interest to a predetermined treatment to determine a reacted formation configuration, wherein the predetermined treatment comprises an acid fluid treatment schedule, and wherein the modeling further comprises modeling acid fluid flow through the formation of interest having the porosity profile, and wherein the modeling further comprises accounting for acid reaction products during the predetermined treatment and shut-in period.

Abstract: Methods and systems for creating a numerical pseudocore model, comprising: a) obtaining logging data from a reservoir having depth-defined intervals of the reservoir, and processing the logging data into interpretable borehole image data having unidentified borehole image data; b) examining one of the interpretable borehole image data, other processed logging data or both to generate the unidentified borehole image data, processing the generated unidentified borehole image data into the interpretable borehole image data to generate warped fullbore image data; c) collecting one of a core from the reservoir, the logging data or both and generating a digital core data from one of the collected core, the logging data or both such that generated digital core data represents features of one or more depth-defined interval of the reservoir; and d) processing generated digital core data, interpretable borehole image data or the logging data to generate realizations of the numerical pseudocore model.

Abstract: The subject disclosure relates to matrix acidizing. More specifically, the subject disclosure relates to manipulating downhole pressure to promote in-situ mixing. In particular, downhole pressure is temporarily reduced to allow churning of the dissolved CO2 to facilitate mixing efficiency within the wormholes and the matrix around the wormholes.

Abstract: This subject disclosure describes methods to build and/or enhance 3D digital models of porous media by combining high- and low-resolution data to capture large and small pores in single models. High-resolution data includes laser scanning fluorescence microscopy (LSFM), nano computed tomography (CT) scans, and focused ion beam-scanning electron microscopy (FIB-SEM). Low-resolution data includes conventional CT scans, micro computed tomography scans, and synchrotron computed tomography scans.

Abstract: The subject disclosure relates to methods for determining representative element areas and volumes in porous media. Representative element area (REA) is the smallest area that can be modeled to yield consistent results, within acceptable limits of variance of the modeled property. Porosity and permeability are examples of such properties. In 3D, the appropriate term is representative element volume (REV). REV is the smallest volume of a porous media that is representative of the measured parameter.

Abstract: This disclosed subject matter is generally related to methods for characterizing two-dimensional (2D) and three-dimensional (3D) samples to determine pore-body and pore-throat size distributions and capillary pressure curves in porous media using petrographic image analysis. Input includes high-resolution petrographic images and laboratory-derived porosity measurements. Output includes: (1) pore-body and pore-throat size distributions, and (2) simulated capillary pressure curves for both pore bodies and pore throats.

Abstract: Methods for upscaling digital rock modeling data are described. Core-plug samples for pore-scale modeling are strategically chosen using whole-core minipermeability grids and conventional CT (Computed Tomography) scans. Pore models or pore-network models are used for flow modeling. Computed numerical SCAL (Special Core AnaLysis) properties are validated using laboratory-derived data, then they are used to populate borehole-scale models. Borehole-scale models use MPS (Multi-Point Statistics) to combine minipermeability grids and conventional CTscans of whole core with electrical borehole images to create 3D numerical pseudocores for each RRT (Reservoir Rock Type). SCAL properties determined from pore-scale models are distributed for each petrophysical facies in numerical pseudocores. Effective SCAL properties computed from various MPS borehole-scale realizations or models are used to populate interwell-scale models for each RRT.

Abstract: Methods for characterizing a three-dimensional (3D) sample of porous media using at least one measuring tool that retrieves two or more set of transmitted measured data at two or more depths of the sample, such that the retrieved two or more set of transmitted measured data is communicated to a processor and computed in at least one multi-point statistical (MPS) model.

Abstract: Methods and systems for creating a numerical pseudocore model, comprising: a) obtaining logging data from a reservoir having depth-defined intervals of the reservoir, and processing the logging data into interpretable borehole image data having unidentified borehole image data; b) examining one of the interpretable borehole image data, other processed logging data or both to generate the unidentified borehole image data, processing the generated unidentified borehole image data into the interpretable borehole image data to generate warped fullbore image data; c) collecting one of a core from the reservoir, the logging data or both and generating a digital core data from one of the collected core, the logging data or both such that generated digital core data represents features of one or more depth-defined interval of the reservoir; and d) processing generated digital core data, interpretable borehole image data or the logging data to generate realizations of the numerical pseudocore model.