Abstract: Light from a light source that has interacted with a sample of downhole fluid provided in a downhole optical tool is sequentially passed through a plurality of groups of light filters, each of the groups of light filters including of one or more light filters, to generate a data set for each of the groups of light filters, also referred to as a simultaneous channel group. The data generated for each of the simultaneous channel groups is then analyzed to determine if the data from that simultaneous channel groups is effective in providing information useful for the analysis of the sample of downhole fluid.

Abstract: A feed storage arrangement for use with a sheet like feed barrier, the storage arrangement comprising at least one elongated leachate channel having an outlet end; and at least a first feed pad section extending along at least a portion of a length dimension of the leachate channel, the first pad section including first and second lateral edges and upper and lower edges wherein the first lateral edge is located proximate the leachate channel, the second edge is spaced apart from the first edge, the upper edge is proximate the outlet end of the leachate channel, and the lower edge is opposite and spaced from the upper edge, the first pad section sloped downward starting at the second edge and toward the first edge, wherein, with feed supported on the first pad section adjacent the leachate channel, the feed barrier is positionable on top of the feed with an edge portion extending over the leachate channel to a side of the leachate channel opposite the first pad section.

Abstract: Improved systematic inversion methodology applied to formation testing data interpretation with spherical, radial and/or cylindrical flow models is disclosed. A method of determining a parameter of a formation of interest at a desired location comprises directing a formation tester to the desired location in the formation of interest and obtaining data from the desired location in the formation of interest. The obtained data relates to a first parameter at the desired location of the formation of interest. The obtained data is regressed to determine a second parameter at the desired location of the formation of interest. Regressing the obtained data comprises using a method selected from a group consisting of a deterministic approach, a probabilistic approach, and an evolutionary approach.

Abstract: A downhole fluid sampling tool comprising one or more probes configured to take at least one fluid sample from the wellbore and perform a Saturates, Aromatics, Resins, Asphaltenes (SARA) analysis on the at least one fluid sample. Additionally, the downhole fluid sampling tool comprises an information handling system for developing a first remediation operation based at least in part on the first SARA analysis and performing the first remediation operation on the first fluid sample to form a first remediated fluid sample.

Abstract: In general, in one aspect, embodiments relate to a method, that includes lowering a downhole tool to a target depth of a wellbore, sampling reservoir fluid containing asphaltene at the target depth using the downhole tool, controlling a pressure of the sampled reservoir fluid while downhole to induce one or more phase transitions of the asphaltene, measuring the sampled reservoir fluid after inducing the one or more phase transitions, and identifying fluid composition of the reservoir fluid based on the measuring.

Abstract: A test tool attached to test string comprising a fluid conduit is deployed to a test position within a wellbore. The deployment includes hydraulically isolating a portion of the wellbore proximate the test tool to form an isolation zone containing the test position. A fluid inflow test is performed within the isolation zone and an initial formation property and a fluid property are determined based on the fluid inflow test. A fluid injection test is performed within the isolation zone including applying an injection fluid through the test string into the isolation zone, wherein the flow rate or pressure of the injection fluid application is determined based, at least in part, on the at least one of the formation property and fluid property.

Abstract: A method and system for correlating two or more logs. The method may include reviewing an openhole log to identify one or more depths within a wellbore for testing, disposing a fluid sampling tool into the wellbore, creating a correlation log with the fluid sampling tool, depth-matching the correlation log to the openhole log to create a relative shift table, and moving the fluid sampling tool to the one or more depths within the wellbore based at least in part on the relative shift table. The system may include a fluid sampling tool disposed in a wellbore to create a correlation log and an information handling system connected to the fluid sampling tool.

Abstract: A sole structure for an article of footwear includes a midsole having a top surface, a bottom surface opposite the top surface, and a peripheral surface extending between the top surface and the bottom surface. The bottom surface includes a recess defining a first opening in the peripheral surface. The sole structure for an article of footwear also includes an insert disposed within the recess and including a first material having a first gloss unit value and a second material disposed on an outer surface of the first material and having a second gloss unit value. The second material is at least partially disposed within the first opening.

Abstract: A formation tester comprises a body having an outlet; a probe extendable from the body and having a sealing pad; and a flow line within the body, wherein the flow line has an entry end connectable to the probe and has an exit end connectable to the outlet in the body; and a reactive filter material in the flow line downstream of the entry end of the flow line, wherein the reactive filter material sorbs and entraps an analyte in a wellbore fluid.

Abstract: The present invention is directed to curable film-forming compositions and coating kits, each comprising: (a) a polyepoxide functional polymer; (b) a polythiol functional compound, wherein the polythiol functional compound comprises at least two or at least three thiol functional groups and wherein if the polythiol functional compound contains hydroxyl functional groups, the ratio of thiol functional groups to hydroxyl functional groups within the polythiol functional compound is not 1:1; (c) a reactive compound different from the polythiol functional compound (b), containing multiple pendant and/or terminal functional groups selected from carboxylic acid, anhydride, amine and phenol that are reactive with epoxide functional groups; and (d) a pigment. The curable film-forming composition demonstrates a pigment to binder ratio greater than or equal to 2 and less than 3, adhesion to diverse substrates, and fast sandability.

Abstract: A method and non-transitory storage computer-readable medium for performing a neural operator on one or more wellbore measurements. The method may comprise o obtaining one or more measurements, performing a measurement normalization on the one or more measurements to form one or more normalized measurements, forming a material function with the one or more normalized measurements, and forming a neural operator generated physical response with a neural operator and the material function. The method may further comprise forming a beamforming map with the one or more measurements, and forming a neural operator leak source location map with a neural operator and the one or more measurements.

Abstract: A device for temporarily protecting a neck of an aneurysm of a blood vessel is provided. The device includes a plurality of wires coiled to form a collapsible frame configured to expand and substantially conform to a shape of an inside surface of the blood vessel while the aneurysm is being treated. The device includes a retention wire disposed at a proximal end of the frame of the plurality of wires. The device includes a cover comprising at least a first portion configured to be disposed directly against a neck of the aneurysm while the aneurysm is being treated, the first portion having a first porosity to blood flow. Related methods of use and manufacturing are also provided.

Abstract: A method and system for identifying a fluid within a subterranean formation. The method may comprise obtaining one or more pressure measurements at one or more depths with a downhole fluid sampling tool, forming a depth-pressure measurement set form the one or more pressure measurements, creating a solution novelty threshold from at least the depth-pressure measurement set, constraining a solution space with the solution novelty threshold, and finding a solution-space-inscribed simplex within the solution novelty threshold. The method may further comprise generating a simplicial decomposition for a convex hull of the solution-space-inscribed simplex up to the solution novelty threshold, identifying at least one inscribed simplex within the convex hull of the solution-space-inscribed simplex, determining a novel simplex interior with the at least one inscribed simplex, and forming a plurality of solutions with the novel simplex interior.

Abstract: Systems and methods of the present disclosure relate to signal attenuation for acoustic logging tools. An acoustic logging tool includes acoustic transducers. Each acoustic transducer includes a body, a piezoelectric element disposed on a first end of the body to receive or transmit at least one signal, and a wedge-cut disposed on an opposite end of the body. The wedge-cut defines a sloped portion operable to attenuate signals.

Abstract: In some embodiments, a downhole logging tool configured for placement in a wellbore comprises a first magnet configured to activate a first volume of ferromagnetic fluid disposed between the downhole logging tool and the wellbore to achieve a first seal between a primary analysis region of the downhole logging tool and a wellbore fluid.

Abstract: Quality factors associated with formation pressure measurements at various depths in the geologic formation are determined based on one or more well logs of formation properties in a geologic formation. A formation testing tool with two or more probes is positioned in a borehole of the geologic formation based on the quality factors. The two or more probes in the borehole perform respective formation pressure measurements, where each formation pressure measurement is performed at a different depth. The formation pressure measurements and the given distance between the two or more probes indicate a formation pressure gradient.

Abstract: A method comprises receiving a measurement of a pressure in a subsurface formation at a number of depths in a wellbore formed in the subsurface formation across a sampling depth range of the subsurface formation to generate a number of pressure-depth measurement pairs and partitioning the sampling depth range into a number of fluid depth ranges. The method comprises performing a fitting operation over each of the number of fluid depth ranges to determine a fluid gradient for the type of the reservoir fluid for each of the number of fluid depth ranges. The method comprises generating a solution set of one or more solutions based on the fluid gradient of the reservoir fluid for each of the number of fluid depth ranges determined from performing the fitting operation, wherein each solution defines a partitioning of the sampling depth range and the fluid gradient of each fluid depth range.

Abstract: A system to determine a contamination level of a formation fluid, the system including a formation tester tool to be positioned in a borehole, wherein the borehole has a mixture of the formation fluid and a drilling fluid and the formation tester tool includes a sensor to detect time series measurements from a plurality of sensor channels. The system includes a processor to dimensionally reduce the time series measurements to generate a set of reduced measurement scores in a multi-dimensional measurement space and determine an end member in the multi-dimensional measurement space based on the set of reduced measurement scores, wherein the end member comprises a position in the multi-dimensional measurement space that corresponds with a predetermined fluid concentration. The processor also determines the contamination level of the formation fluid at a time point based the set of reduced measurement scores and the end member.