Abstract: A model is used to generate corrections to mitigate ideal condition artifacts in acoustic property values of an annular material in a cased wellbore. A mathematical model that generates acoustic property values at ideal conditions introduces artifacts into the acoustic property values. Acoustic measurements of an annular material are used to generate features that represent wellbore conditions and are not accounted for in the mathematical model that generates acoustic property values. A model will generate corrections for acoustic property values of an annular material with the features to yield a more accurate acoustic property profile for the annular material of a cased hole.

Abstract: A monitoring system for monitoring a pipeline can include a sampling unit, a spectroscopy system, and a waste handling system. The sampling unit can include a sampling point for capturing a representative sample of a fluid flow in the pipeline. The spectroscopy system can be configured to chemically analyze the representative sample with respect to components of the fluid flow. Additionally, the spectroscopy system can be configured to detect a corrosive component of the fluid flow. The waste handling system can remove the representative sample from the spectroscopy system.

Abstract: Process control for a pipeline can be adjusted based on spectroscopic measurements from a monitoring system. For example, a computing system can receive, from the spectroscopic monitoring system, a spectroscopic measurement with respect to fluid flow in the pipeline. The computing system can determine that an amount of a corrosive component in the fluid flow exceeds a predetermined threshold for the process control. In response to determining that the corrosive component in the fluid flow exceeds the predetermined threshold, the computing system can determine an adjustment to the process control for the fluid flow usable to maintain a compositional stability of the fluid flow. Then, the computing system can output the adjustment to a pipeline tool to maintain the compositional stability of the fluid flow.

Abstract: Systems, methods, and devices of a health device network may include: a non-invasive glucometer that non-invasively measures analyte levels; an invasive glucometer communicatively coupled directly to the non-invasive glucometer; a cloud-based server communicatively coupled to the non-invasive glucometer or the invasive glucometer; a user device communicatively coupled to the cloud-based server; and/or a user interface that displays the invasive glucose measurement, the non-invasive glucose measurement, a data batch, and/or processed data to the user. The non-invasive glucometer and/or the invasive glucometer may aggregate an invasive glucose measurement and a non-invasive glucose measurement into the data batch.

Abstract: A downhole tool comprises at least one inlet and a first pump coupled to the at least one inlet via a first flow line. The first pump is to pump at a first pump rate to extract fluid via the at least one inlet from a subsurface formation in which a borehole is created and in which the downhole tool is to be positioned. A sample chamber is coupled to the inlet via a second flow line, and a second pump is coupled to the inlet via the second flow line. The second pump is to pump at a second pump rate to extract the fluid via the at least one inlet from the subsurface formation and for storage in the sample chamber. The first pump rate is greater than the second pump rate.

Abstract: Systems and methods for performing a contamination estimation of a downhole sample comprising at least a formation fluid and/or a filtrate are provided. A plurality of downhole signals are obtained from the downhole sample and one or more of the signals are conditioned. At least two of the conditioned signals or downhole signals are fused into a multivariate dataset. From optical and density properties of the formation fluid and/or of the filtrate, a multivariate calculation is performed to generate concentration profiles of the formation fluid and the filtrate.

Abstract: A method for estimating a thickness for each of a plurality of nested tubulars may include disposing an electromagnetic (EM) logging tool in a wellbore, transmitting an electromagnetic field from the transmitter into one or more tubulars to energize the one or more tubulars with the electromagnetic field thereby producing an eddy current, and measuring the electromagnetic field generated by the eddy current. Additionally, the method may include defining a prior distribution of at least one pipe thickness log based on the plurality of measurements, processing a first set of measurement depth points to estimate one or more tubulars at one or more depths in the wellbore, computing a posterior distribution of the thickness log based at least in part on the prior distribution and the one or more thicknesses, and determining a second set of measurement depth points to process based on the posterior distribution.

Abstract: A fluid flow rate sensor. The fluid flow rate sensor comprises an elongated structure; a heating element installed into a first end of the elongated structure; a first temperature transducer coupled to an outside of the elongated structure at a first predefined location; a second temperature transducer coupled to the outside of the elongated structure at a second predefined location; and a control unit that is configured to turn the heating element on and off, to analyze a first temperature indication received from the first temperature transducer, to analyze a second temperature indication received from the second temperature transducer, to determine a flow rate of a fluid that is in intimate contact with the outside of the elongated structure based on analyzing the first temperature indication and the second temperature indication, and to output the flow rate via a communication line.

Abstract: Described herein are systems and techniques for monitoring substances that are injected into an Earth formation whether that be CO2 from a carbon capture and storage (CCS) process, or water or steam injected for an enhanced oil recovery (EOR) process. Components located on an outside of a wellbore casing may be electrically isolated from components located on the inside of the wellbore casing. Data and/or power may be transferred through the wellbore casing wirelessly in order to increase the reliability of a data collection system because the need for wires to be placed on the outside surface of a wellbore casing is eliminated. The components located on the outside of the casing may receive electromagnetic (EM) or transmit EM fields as part of a system that collects data about substances that are injected into Earth formations during a CCS or EOR process.

Abstract: Described herein are systems and techniques for monitoring substances that are injected into an Earth formation whether that be CO2 from a carbon capture and storage (CCS) process, or water or steam injected for an enhanced oil recovery (EOR) process. Components located on an outside of a wellbore casing may be electrically isolated from components located on the inside of the wellbore casing. Data and/or power may be transferred through the wellbore casing wirelessly in order to increase the reliability of a data collection system because the need for wires to be placed on the outside surface of a wellbore casing is eliminated. The components located on the outside of the casing may receive electromagnetic (EM) or transmit EM fields as part of a system that collects data about substances that are injected into Earth formations during a CCS or EOR process.

Abstract: An example method of application identification in a virtualized computing system having a cluster of hosts, the hosts including virtualization layers supporting virtual machines (VMs), is described. The method includes: executing, by application analysis software, process discovery agents for the VMs; receiving, at the application analysis software from the process discovery agents, process metadata describing processes executing on the VMs; generating signatures for the processes based on the process metadata; and determining components of an application based on the signatures.

Abstract: The present application relates sensing reactive components in fluids by monitoring band gap changes to a material having interacted with the reactive components via physisorption and/or chemisorption. In some embodiments, the sensors of the present disclosure include the material as a reactive surface on a substrate. The band gap changes may be detected by measuring conductance changes and/or spectroscopic changes. In some instances, the sensing may occur downhole during one or more wellbore operations like drilling, hydraulic fracturing, and producing hydrocarbons.

Abstract: A system includes a pipe string; a wireline cable run through the pipe string; and a downhole tool for formation testing, wherein the downhole tool comprises, an upper assembly, an impeller unit connected to a downhole end of the upper assembly, wherein the impeller unit comprises a first impeller coupled to a second impeller by a shaft, a first flowline having a first end that is open to the formation, a packer unit that isolates a portion of a borehole surrounding the first end of the first flowline from the rest of the borehole, and a tool string connected to the first flowline, wherein the tool string hydraulically connects the packing device to the upper assembly.

Abstract: Disclosed herein are non-egg compositions that can be used as egg substitutes. The disclosure is directed to egg substitutes and methods of manufacturing the same, and compositions comprising the egg substitutes, including edible compositions such as baked goods and edible emulsions.

Abstract: A system can be provided that can include a measurement tool that can be coupled to a conveyance mechanism for positioning the measurement tool downhole in a wellbore. The wellbore can be encased by a tubular. The system can further include a vibration-inducing device that can cause the tubular to vibrate. Additionally, the system can include an interferometer coupled to the measurement tool for detecting the vibration in the tubular. The system can further generate data useable to determine at least one status of the tubular and at least one status of a cement layer. The cement layer can be positioned between the tubular and a subterranean formation surrounding the wellbore.

Abstract: Embodiments of the present disclosure disclose a method and a system for video anomaly detection. The system is configured to collect a sequence of input video frames of an input video of a scene. In addition, the system is configured to partition each input video frame of the sequence of input video frames into a plurality of input video patches. Further, the system is configured to process each of the plurality of input video patches with one or more classifiers. Each of the one or more classifiers corresponds to a deep neural network trained to estimate one or more attributes of the plurality of input video patches from an output of a penultimate layer of the deep neural network. Furthermore, the system is configured to compare the output of the penultimate layer. The system is further configured to detect an anomaly based on the output of the penultimate layer.

Abstract: Provided is a composition containing a redox charge-transfer complex of an electron donor polymer and an electron acceptor compound where the anionic form of the electron acceptor has a reduction potential higher than the reduction potential of the electron donor polymer; at least one metal salt and at least one additive compound having a dielectric constant of 10 or greater. The composition is a free-flowing, substantially amorphous powder and is useful as a metal ion conducting component of electrolytic cells.

Abstract: According to embodiments, a geosynthetic structure includes a base resin polymeric matrix including an admixture. The geosynthetic structure further includes a graphene material impregnated into the base resin polymer matrix and in a final amount of about 0.10 weight percent to about 5 weight percent. The geosynthetic structure also includes a stabilizer impregnated within the base resin polymer matrix.

Abstract: A method may comprise disposing a downhole pressure sampling tool into a wellbore; calculating a prior distribution based at least in part on one or more proxy logs, moving the downhole pressure sampling tool to a first location in the wellbore, taking at least one measurement with the downhole pressure sampling tool at the first location in the wellbore, calculating a posterior distribution based at least in part on the at least one measurement and the prior distribution, identifying a second location based at least in part on the posterior distribution, and moving the downhole pressure sampling tool to the second location.