Abstract: A method of processing a core sample includes the steps of: hermetically sealing the core sample in a chamber of an enclosure, comminuting the core sample while the chamber is hermetically sealed, injecting a hydrophilic agent into the chamber, wherein a slurry is formed by at least the hydrophilic agent and water released by the core sample, extracting at least a portion of the slurry from the chamber, separating a fluid from the slurry, analyzing the separated fluid to estimate an amount of water in the fluid, and estimating a water content of the core sample using the estimated amount of water in the fluid.

Abstract: A tracer particle includes a silica core and a plurality of polymer-coated oligonucleotides disposed within the silica core, on a surface of the silica core, or a combination thereof. Each of the polymer-coated oligonucleotides comprise a polymer that at least partially surrounds an oligonucleotide.

Abstract: An apparatus for analyzing a core sample obtained from a subterranean formation includes a neutron generator, a plurality of detectors, a computed tomography scanner, an information processing device, and a transport system. The neutron generator can operate in a pulsed mode and emit neutrons into the core sample.

Abstract: The present disclosure includes a core sample analysis system that includes a portable sampling device configured to be positioned adjacent to a subsurface core sample. The portable sampling device includes a first module that includes a radiation source. Also, the portable sampling device includes a second module that includes a detector that is configured to detect radiation emitted from the radiation source that reflects off of the subsurface core sample.

Abstract: A modular lifting system, including an enclosable lifting device support structure. The enclosable lifting device support structure includes a deployable top, a plurality of lateral sides, a base coupled to the plurality of lateral sides, and a plurality of extension arms. The deployable top is configured to support a lifting device on a first side of the deployable top. The plurality of extension arms are configured to extend and support the deployable top when the deployable top is deployed.

Abstract: A modular lifting system, including an enclosable lifting device support structure. The enclosable lifting device support structure includes a deployable top, a plurality of lateral sides, a base coupled to the plurality of lateral sides, and a plurality of extension arms. The deployable top is configured to support a lifting device on a first side of the deployable top. The plurality of extension arms are configured to extend and support the deployable top when the deployable top is deployed.

Abstract: According to various embodiments, a method may include measuring a first capacitance of a sample at a first frequency using a measurement system, measuring a second capacitance of the sample at a second frequency using the measurement system, calculating a ratio of the first capacitance to the second capacitance, and determining a formation water resistivity or conductivity of the sample using the ratio.

Abstract: According to various embodiments, a method may include supplying a gas to an upstream side of a core holder containing a core sample, accumulating permeated gas that has flowed through the core sample in a cavity coupled to a downstream side of the core holder, measuring an elapsed time during which the permeated gas accumulates in the cavity using a timer, measuring a pressure of the permeated gas using a pressure transducer coupled to the cavity, and determining a gas permeability of the core sample based at least in part on the pressure of the permeated gas and the elapsed time.

Abstract: According to various embodiments, a method may include measuring a first capacitance of a sample at a first frequency using a measurement system, measuring a second capacitance of the sample at a second frequency using the measurement system, calculating a ratio of the first capacitance to the second capacitance, and determining a formation water resistivity or conductivity of the sample using the ratio.

Abstract: A method of preparing a thin section sample includes affixing the sample to a receptacle using an affixing media that includes a material having a thickness-sensitive characteristic. The sample may then be shaped to have an asymmetric cross-section. The method may further include reducing a thickness of the material until the thickness-sensitive material exhibits a change in an optical characteristic. The added material, which may be quartz, may exhibit a predetermined optical characteristic at a specified thickness and/or exhibit a change in an optical characteristic in response to a change in thickness. In one application, the method may include retrieving the sample from a subterranean formation. For instance, the sample may be retrieved from a gas shale formation.

Abstract: A system for determining a parameter of interest of at least one particle in a sample of a fluid obtained from a formation, comprises a view cell containing at least a portion of the sample and at least one window for viewing the sample. A light source illuminates the sample. An imaging system captures at least one image of the illuminated sample. A program executing a set of instructions on a computer analyzes the at least one image and generates an output related to at least one parameter of interest of the at least one particle in said sample.

Abstract: The extent of invasion of a water-based drilling fluid into a formation may be determined using at least two tracers where one is deuterium oxide and the other is a water-soluble tracer. One such method includes introducing a drilling fluid having an aqueous phase and known concentrations of a water-soluble tracer and deuterium oxide into a well drilled into a fluid-producing formation; obtaining a sample of the fluid from the fluid-producing formation at a location adjacent to the well; determining the concentrations of the deuterium oxide and water-soluble tracer in the sample; and calculating the deuterium oxide concentration within the fluid producing formation based on the known and determined concentrations of the water-soluble tracer and deuterium oxide in the drilling fluid and in the sample.

Abstract: A method for determining the extent of recovery of materials injected or otherwise introduced into oil wells or subsurface formations is practiced using a portable device. The portable device can also be used to determiner the occurrence of a predetermined condition in an oil well such as water break through in a production zone, or the opening or closing of a sliding sleeve. When, for example, water breakthrough is detected, the zone producing too much water can be plugged, using, for example, a flow-through bridge plug, if there are other producing zones further downhole.

Abstract: A device for sealing and anchoring within a tubular member. The device comprises a top swage member disposed within the tubular member, with the top swage member having a longitudinal center of axis. Also included is a first sealing member disposed about the top swage member, with the first sealing member containing a first plurality of circumferential ribs disposed about the first sealing member. The device may also include a second sealing member that is attached to the first sealing member, with the second sealing member containing a second plurality of circumferential ribs disposed about the second sealing member. A bottom swage member is disposed within the second sealing member, with the bottom swage member having a longitudinal center of axis. The device further comprises a setting apparatus for driving the top swage longitudinally downward relative to the top swage's longitudinal center axis and for driving the bottom swage longitudinally upward relative to the bottom swage's center axis.

Abstract: A system for determining a parameter of interest of at least one particle in a sample of a fluid obtained from a formation, comprises a view cell containing at least a portion of the sample and at least one window for viewing the sample. A light source illuminates the sample. An imaging system captures at least one image of the illuminated sample. A program executing a set of instructions on a computer analyzes the at least one image and generates an output related to at least one parameter of interest of the at least one particle in said sample.

Abstract: Disclosed is a method of determining the extent of recovery of materials injected into oil wells or subsurface formations. The method includes injection of one or more tracers into an oil well or into a formation. Included in the method are the steps of introducing a material of interest into the oil well or into the subsurface formation associated with the bore of the oil well; introducing a tracer into the oil well or into the subsurface formation associated with the bore of the oil well; recovering from the oil well a production fluid, analyzing the production fluid for a concentration of the chemical tracer present in the production fluid; and calculating the amount of material of interest recovered from the oil well using the concentration of the chemical tracer present in the production fluid as a basis for the calculation.

Abstract: A system for determining a parameter of interest of at least one particle in a sample of a fluid obtained from a formation, comprises a view cell containing at least a portion of the sample and at least one window for viewing the sample. A light source illuminates the sample. An imaging system captures at least one image of the illuminated sample. A program executing a set of instructions on a computer analyzes the at least one image and generates an output related to at least one parameter of interest of the at least one particle in said sample.

Abstract: The present invention provides a method and system for distributed residual tomographic velocity analysis using dense residual depth difference maps. Prestack seismic imaging is performed using an initial velocity field and interpreted horizons. A residual depth difference is estimated referenced to fixed offset and all horizons. Residual depth difference maps are computed for each offset and each horizon. The residual depth difference maps are back projected to determine slowness perturbation. The initial velocity model may be converted to slowness and the estimated slowness is composited therewith to produce a new slowness volume. The new slowness volume is converted to a new velocity volume for performing prestack seismic imaging. This process is repeated until the slowness perturbation is negligible or reaches a predetermined threshold.

Abstract: In one embodiment, the invention includes a method for estimating seismic signal propagation raypaths from seismic source locations through a subsurface formation to seismic receiver locations. Raypaths are determined which minimize the value of an expression which is a function of travel time and distance between a source location and a receiver location. The value of the expression depends on the value of a parameter which balances the weighting of travel time and distance in the expression.

Abstract: The present invention provides a method and system for processing an input seismic record to suppress noise energy, for example multiple energy, and to enhance signal. A primary signal component is determined from an input seismic record. A residual record is obtained from the input seismic record and the determined primary component record, for example, by determining a difference of the two records. A next primary signal component record is then obtained from the residual record. The primary component record and the next primary component record are combined to form a reconstructed record. A subsequent residual record may then be obtained and further primary signal components extracted.