Abstract: An ESP system having a driveshaft assembly; an electrical motor coupled with an end of the driveshaft assembly, and that when energized rotates the driveshaft assembly in a first direction. The ESP system also includes a pump coupled with an end of the driveshaft assembly distal from the motor, and a one-way clutch train in the driveshaft assembly that arrests rotation of the driveshaft assembly in a second direction. In this example the driveshaft assembly includes a pump shaft having an end engaged with an end of a motor shaft; opposing ends of the pump and motor shafts respectively couple with the pump and motor. The one-way clutch train includes a shaft-to-shaft clutch coupled between inner and outer surfaces of the pump and motor shafts and a shaft to housing clutch coupled between an outer surface of one of the pump and motor shafts and an outer housing.

Abstract: Halite scales in an oilfield brine that has a potential for halite scaling can have halite scale formation inhibited or prevented by adding an effective amount of an additive, where the additive contains at least one non-water-soluble quaternary ammonium compound and at least one organic solvent. The quaternary ammonium compound may be benzyl-alkyldimethyl ammonium chloride, where the alkyl group has from 2 to 30 carbon atoms. The organic solvent may be one or more alcohol or glycol.

Abstract: A scale inhibitor squeeze treatment is enhanced by injecting a pre-flush solution into a wellbore, where the pre-flush solution includes at least one organic carbonate solvent, such as a dialkyl carbonate and/or a cyclic carbonate. The use of an organic carbonate solvent can help prevent the pre-flush solution emulsion formation, help avoid water-blocking, and enhance scale inhibitor adsorption. The use of an organic carbonate solvent also permits the pre-flush solution to be free of water, in one non-limiting embodiment.

Abstract: A system includes a Christmas tree (XT) having at least one valve, the XT being coupled to a wellbore. The system also includes a pressure boundary tool adapted to provide a secondary boundary for the XT. The pressure boundary tool includes a plug body to be positioned against a valve member of the at least one valve; a seal to be energized into a valve body of the at least one valve; and a plate arranged proximate the seal, the plate being moveable between a first position and a second position, the first position energizing the seal and a second position deenergizing the seal. The pressure boundary tool is positioned within the XT on a side of the valve member closer to the wellbore.

Abstract: In at least one embodiment, a well inspection method and system enables transmission of an acoustic signal from a well inspection tool into a well structure and reception of return signals from the well structure at an array of receivers on the well inspection tool. The method and system enable performing of Short-Term Fourier Transform (STFT) on the return signals to generate spectrogram data that is used to determine short-term power spectra of the return signals. Time-dependent frequency response and location-dependent waveform propagation patterns are identified from the short-term power spectra. Cement bonding conditions is determined based on pattern matching using the time-dependent frequency response patterns and using the location-dependent waveform propagation patterns.

Abstract: Wellbore ranging methods and systems for active electromagnetic ranging between a pair of conductive tubulars. Methods may include generating a depth-dependent current on one conductive tubular of the pair and a return current on another and thereby causing an injection current to flow into the earth formation by electrically exciting a first conductive tubular of the pair at a first wellhead and a second of the pair at a second wellhead, wherein the return current on the one results from the injection current on the other and is received from the earth formation; making electromagnetic measurements indicative of at least one electromagnetic field resulting from the depth-dependent current in the earth formation; and estimating a relative position of the first conductive tubular with respect to the second tubular using the electromagnetic measurements.

Abstract: Cutting elements for earth-boring tools may include a cutting edge located proximate to a periphery of the cutting element. The cutting edge may be positioned and configured to contact an earth formation during an earth-boring operation. The cutting edge may include a first portion having a first radius of curvature and a second portion having a second, larger radius of curvature. The second portion may be circumferentially offset from the first portion.

Abstract: A submersible well pump assembly having a motor with a shaft, a stator, a rotor coupled to the shaft, and bearing sleeves between the shaft and a bearing assembly. The rotor includes a number of rotor sections located along an axis of the shaft, where each rotor section includes a stack of rotor disks and end rings on each end of the stack. Each bearing sleeve attaches to an end ring and extends axially away from the end ring into abutment with an end of another bearing sleeve attached to an adjacent end ring.

Abstract: A testing system for a wellbore operation and method of testing a fluid sample from a wellbore. A fluid sample is obtained from the wellbore operation. The fluid sample is received at a first test station having a first robot arm for performing a test on the fluid sample. A controller receives data on the wellbore operation, selects the test based on the data and controls the first robot arm to perform the test. A result of the test is used to adjust a parameter of the wellbore operation.

Abstract: A system for cementing a borehole with foamed cement includes a gas delivery assembly mounted on a movable support structure, the gas delivery assembly configured to supply a gas to a cement slurry to generate a foamed cement slurry. The gas delivery assembly includes a heating element in thermal communication with a gas supply, a temperature sensor, a pressure sensor, a flow meter, and an automated control valve in fluid communication with the gas supply. The gas delivery assembly also includes a control module including a processing device configured to control a temperature and a flow rate of the gas supplied to the cement slurry based on a desired flow rate and measurements from the temperature sensor, the pressure sensor and the flow meter.

Abstract: A system for cementing a borehole with foamed cement includes a gas delivery assembly mounted on a movable support structure, the gas delivery assembly configured to supply a gas to a cement slurry to generate a foamed cement slurry. The gas delivery assembly includes a heating element in thermal communication with a gas supply, a temperature sensor, a pressure sensor, a flow meter, and an automated control valve in fluid communication with the gas supply. The gas delivery assembly also includes a control module including a processing device configured to control a temperature and a flow rate of the gas supplied to the cement slurry based on a desired flow rate and measurements from the temperature sensor, the pressure sensor and the flow meter.

Abstract: Methods for determining mineral compositions of materials are described. The methods include obtaining elemental data associated with a geologic sample, calculating a measurement correlation matrix of the geologic sample from the elemental data, calculating an artificial correlation matrix, comparing the measurement correlation matrix and the artificial correlation matrix to determine an error value, minimizing the error value by updating the artificial correlation matrix and comparing the measurement correlation matrix to the updated artificial correlation matrix, and determining a mineral composition of the geologic sample based on the minimized measurement correlation matrix.

Abstract: Methods, systems, devices, and products for hydrocarbon tubular evaluation. Methods comprise conveying the logging tool in the tubular with a carrier; inducing with a transmitter a horizontal shear (SH) wave; identifying higher order SH mode signals received at a plurality of offset receivers responsive to a higher order SH mode engendered by the horizontal shear (SH) wave; estimating a dominant frequency for higher order SH mode from the higher order SH mode signals; estimating a group velocity for the higher order SH mode from the higher order SH mode signals; and estimating a tubular parameter using the dominant frequency and the group velocity. The tubular parameter may be at least tubular thickness. The method includes estimating the tubular parameter independent of the fundamental horizontal shear wave mode (SH0).

Abstract: In one implementation, a method includes receiving data characterizing a hierarchical dataset associated with hierarchical industrial assets. The hierarchical dataset can include a plurality of node data that can include a plurality of asset data and a plurality of edge data. An edge datum of the plurality of edge data is indicative of a relation between a pair of node data of the plurality of node data. Each node datum of the plurality of node data represents an asset in the hierarchical industrial asset and each edge datum of the plurality of edge data represents an edge in the hierarchical industrial asset. The method further includes receiving data characterizing a partition identifier associated with the hierarchical dataset can be received. The method also includes assigning, based on the partition identifier, a partition of a database to the hierarchical dataset. The method further includes storing the hierarchical dataset in the assigned partition.

Abstract: Dispersants including at least one organic carbonate can keep deposits dispersed within hydrocarbons, where the solids are asphaltenes and derivatives from triazine-based H2S scavengers.

Abstract: A hydraulic tool includes a rotor rotatably disposed within a stator. At least an inner portion of the stator and/or at least an outer portion of the rotor is configured to be installed in a drill string in either of two inverted orientations along a longitudinal axis of the hydraulic tool. The rotor is configured to rotate within the stator in either of the two orientations. A method includes disposing a rotor within a cavity defined by a stator, passing a fluid through the stator to rotate the rotor, and reversing the stator or the rotor. A drilling system includes a fluid source, a hydraulic tool, a drive shaft operatively associated with the rotor of the hydraulic tool, and a drill bit operatively associated with the drive shaft.

Abstract: An electrical submersible pump has a stack of diffusers within the housing, each of the diffusers having a conical upper shoulder and a conical lower shoulder. The lower shoulder of each of the diffusers is in abutment with the upper shoulder of an adjacent one of the diffusers. The upper and lower shoulders of each of the diffusers slope downward and outward relative to the axis. Impeller hubs have conical upper and lower ends. At least some of the upper ends of the hubs abut and transfer up thrust to the lower end of an adjacent one of the hubs. At least some of the lower ends of the hubs abut and transfer down thrust to the upper end of an adjacent one of the hubs.

Abstract: A method of estimating a wettability characteristic of a rock and fluid system includes acquiring a sample of the rock material, performing a first nuclear magnetic resonance (NMR) measurement of the sample when the sample is in a full water saturation condition, and measuring a first T2 distribution, performing a second NMR measurement of the sample when the sample is in a second partial saturation condition, and measuring a second T2 distribution. The method also includes separating a hydrocarbon component of the second T2 distribution from a water component of the second T2 distribution, applying a fluid substitution model to the water component of the second T2 distribution to generate a computed T2 distribution, and calculating a wettability index (WI) based on a difference between the first T2 distribution and the computed T2 distribution.

Abstract: A leak detection and collection system includes a cap configured to couple to a wellbore component. The system also includes an alert system removably coupled to the cap and a packer coupled to the cap. The packer extends into a bore of the wellbore component and the packer is actuated to seal against the wellbore component and to block flow through the bore. The system further includes a release mechanism coupled to the alert system, a first flow path, an accumulator, and a second flow path. The release mechanism is activated at a first pressure above a first threshold to release the alert system and the second flow path directs flow to the accumulator at a second pressure above a second threshold.

Abstract: A process of manufacturing a composition comprises a particulate drag reducing agent is disclosed. The process comprising: continuously forming a temporary container; introducing an unsaturated monomer component and a radical polymerization component into the temporary container; sealing the temporary container to form a sealed temporary container; allowing the unsaturated monomer component to polymerize in the sealed temporary container to form the drag reducing agent via a radical polymerization reaction, the drag reducing agent having a molecular weight of about 1 million gram/mol to about 50 million gram/mol; and grinding the drag reducing agent to form a composition comprising a particulate drag reducing agent, the particulate drag reducing agent having a particle size of about 1 to about 1,500 microns.