Abstract: A flow control valve configured to be positioned in a tubing in a borehole formed in a subsurface formation, wherein the flow control is used to regulate a flow of an injection fluid into the subsurface formation based on a vapor-transition characteristic of a fluid contained within a chamber of the flow control valve.

Abstract: A method for drilling a well. The method may include detecting stick-slip vibrations at a frequency via a downhole sensor. The method may further include determining a reflection coefficient of a drill bit for the frequency based on at least one of a rotational speed of the drill bit or a torque of the drill bit. The method may also include determining a reflection coefficient of a top drive for the frequency based on at least one of a rotational speed of the top drive or a torque produced by the top drive. The method may further include adjusting a control system in electronic communication with the top drive based on the reflection coefficient of the drill bit for the frequency and the reflection coefficient of the top drive for the frequency.

Abstract: A wireless flow control device includes a shiftable apparatus and a power source configured to provide power to shift the shiftable apparatus from a first position to a second position. The wireless flow control device also includes a valve that forms a first fluid flow path through the wireless flow control device while the shiftable apparatus is in the first position. The wireless flow control device further includes an actuation assembly, which, when actuated, forms a second fluid flow path through the wireless flow control device, and a turbine configured to recharge the power source.

Abstract: Some aspects relate to techniques for calibrating a logging tool. In some implementations, the logging tool may estimate certain unknown properties of a signal based on distances between transmitters and receivers of the logging tool and based on frequencies used by the transmitters and receivers. The logging tool may estimate the unknown properties by interpolating values into a mathematical function related to the above-noted distances and frequencies. After estimating the unknown properties, the logging tool may be deployed into the wellbore, where it may use the estimated properties to process signals received through a subsurface formation.

Abstract: A breaker composition comprising (i) an acid precursor, (ii) an accelerating agent wherein the accelerating agent comprises a Lewis acid and (iii) an aqueous fluid wherein the effective operating temperature of the breaker composition ranges from about 15° C. to about 120° C. A wellbore servicing system comprising (a) an aqueous-based drilling fluid, wherein the aqueous-based drilling fluid forms water-wet solids in the wellbore; and (b) a breaker composition comprising (i) an acid, (ii) an accelerating agent and (iii) an aqueous fluid. A method of dissolving a filtercake comprising contacting the filtercake with a breaker solution comprising (i) an acid precursor, (ii) an accelerating agent and (iii) an aqueous fluid wherein the filtercake comprises calcium carbonate.

Abstract: A downhole tool having a downhole end and an uphole end, including: an anchor assembly positioned proximate to the downhole end; at least one flowmeter assembly selectively positionable from the downhole tool wherein the at least one flowmeter assembly includes a flowmeter having a throughbore generally aligned with an axis of the flowmeter; and a waveguide positioned proximate to the uphole end, wherein the at least one flowmeter assembly is positioned proximate to the anchor, wherein the waveguide extends through the throughbore and is secured at the anchor assembly.

Abstract: A submersible pump assembly. The submersible pump assembly comprises a motor comprising a first drive shaft; a seal section comprising a second drive shaft that is coupled to the first drive shaft of the motor; and a centrifugal pump assembly comprising a third drive shaft that is coupled to the second drive shaft of the seal section and a plurality of pump stages, wherein each pump stage comprises an impeller coupled to the third drive shaft and a diffuser retained by a housing of the centrifugal pump assembly, wherein the diffuser of each pump stage comprises a first plurality of vanes each having a first axial length and a second plurality of vanes each disposed between a pair of vanes of the first plurality of vanes and each having a second axial length, wherein the second axial length is less than the first axial length.

Abstract: A system that includes a first transistor to provide a drive voltage to a coupled inductor is disclosed. The coupled inductor can receive the drive voltage and generate a voltage output. A second transistor can receive a switching voltage generated from the voltage output to isolate a load positionable downhole in a wellbore from a voltage source.

Abstract: A sample handling system receives a downhole sample. The sample handle system conditions the sample using a separator and filters to allow discharge of unwanted liquids and particulates prior to flowing the sample to one or more analyzers. Separating the moisture and particulates from the sample improves the operation of the components of the sample handling system, for example, by eliminating unwanted condensate or moisture. A coalescing filter, for example, may protect a proportional valve by removing unwanted particulates and liquids from the sample. Additionally, main components of the sample handling system are accessible from a front of a housing to allow for ease of repair and replacement.

Abstract: A washpipe free feature may include a housing defining a chamber having a bypass portion and a securing portion. The housing has first and second bores to put the bypass portion in fluid communication with an annulus of a wellbore and a central bore of a downhole tubular, respectively. Further, the washpipe free feature includes a magnet secured in the bypass portion, a ferromagnetic ball disposed within the bypass portion, and a piston disposed within the chamber. A distal end of the piston blocks the ball from contacting the magnet in a run-in position such that the ball may plug the first bore in response to fluid flow from the tubular toward the annulus. Additionally, the piston is slideable to an open position such that the magnet may hold the ball out of a flow path between the first bore and the second bore in the bypass portion.

Abstract: Aspects of the subject technology relate to systems, methods, and computer-readable media for identifying a wellbore pressure based on a predicted pump intake loss. A pump intake pressure after an intake for a submersible pump deployed downhole in a wellbore is identified. An intake loss prediction model for identifying a virtual intake loss associated with the intake for the submersible pump as a function of one or more intake loss parameters is accessed. The virtual intake loss is identified by applying the intake loss prediction model based on intake loss prediction input of the one or more intake loss parameters. A pump intake pressure before the intake for the submersible pump is determined based on the virtual intake loss and the identified pump intake pressure after the intake.

Abstract: A method may comprise introducing an ultrasonic device into a wellbore with a cement slurry therein; generating ultrasonic waves with the ultrasonic device, wherein at least a portion of the ultrasonic waves are transmitted into at least a portion of the cement slurry; creating cavitation within at least the portion of the cement slurry with at least the portion of the ultrasonic waves; and allowing the cement slurry to set to form a hardened mass.

Abstract: A system for landing a perforating gun in a particular orientation may include a landing housing securable within a wellbore and having at least one key slot extending into an inner surface of the landing housing. The system further includes a latch assembly configured to couple to the landing housing in a particular orientation. The latch assembly includes a tubular support structure and at least one key feature configured to extend and retract radially through a sidewall of the tubular support structure. The latch assembly further includes a biasing mechanism configured to bias the at least one key feature into the at least one key slot to couple the latch assembly to the landing housing. Additionally, the system includes a perforating gun system secured to the latch assembly such that the orientation of the latch assembly aims the perforating gun system in the wellbore.

Abstract: A perforating gun system may include a central support structure and a plurality of charges secured to the central support structure. Each charge of the plurality of charges is configured to perforate a casing and/or sidewall of a wellbore upon detonation. Further, the plurality of charges comprises a first group of charges and a second group of charges, and each charge of the second group of charges is radially offset from each charge of the first group of charges with respect to the central support structure.

Abstract: A shaped cutter has a plurality of ridges extending in parallel across a cutting face to enhance drilling. The cutting table is also multi-tapered, being convex along a first cross-section perpendicular to the ridges and concave along a second cross-section parallel with the ridges. The shaped cutter may enhance rock failure modes in addition to shearing, such as by indentation, impacting, scraping and grinding. The plurality of ridges may also exploit vibrations in the drill string to enhance rock failure. The cutting table may be positioned on a drill bit to define an internal back rake angle with respect to a slope angle where the cutting table is concave. The cutting table may include a flared periphery, resulting in a sharper indentation angle and/or larger radius of contact with the formation.

Abstract: A shaped cutter has a plurality of peripheral cutting teeth to enhance drilling. The shaped cutter may enhance rock failure modes in addition to shearing, such as by indentation, impacting, scraping and grinding. The peripheral cutting teeth are located along the periphery, where cutting energy and forces may be highest. An open region radially inward of the peripheral cutting teeth may be axially recessed to increase the proportion of cutting load on the peripheral cutting teeth. The cutting table may be tapered to modify a back rake angle. The flared periphery may result in a sharper indentation angle and/or larger radius of contact. The plurality of cutting teeth may also exploit vibrations in the drill string to enhance rock failure.

Abstract: Various shaped cutters are disclosed for use on a drill bit or other wellbore forming tool. In one aspect, the shaped cutter includes a plurality of radial ridge sets. Each radial ridge set includes a plurality of ridges radially extending along the cutting table between a periphery of the cutting table and the cutter axis. The cutter may be positioned on the drill bit with one of the radial ridge sets exposed to the formation so the ridges may generate multiple cracks in the formation while drilling. After the current radial ridge set becomes worn, the cutter may be repositioned on the drill bit to expose another one of the radial ridge sets, such as during a repair, refurbish, or maintenance operation. The plurality of ridges may also exploit vibrations in the drill string to enhance rock failure.

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.

Abstract: Piston-less downhole tools and piston-less pressure compensation tools are presented. The piston-less downhole tool includes a first chamber comprising a first fluid, the first fluid being a fluid that thermally expands in response to an increase in a temperature of the first fluid. The piston-less downhole tool also includes a tubular having a first end that is fluidly sealed and a second end that is in fluid communication with the first fluid, wherein the tubular is configured to expand in response to thermal expansion of the first fluid. The piston-less downhole tool further includes a second chamber configured to store a second fluid. The tubular of the piston-less downhole tool is configured to contract in response to pressure applied by the second fluid.

Abstract: A method for determining the presence and bonding characteristics of elements which may include cement which may be bonded to a pipe string. The method for determining the presence and bonding may comprise disposing an acoustic logging tool in a wellbore, wherein the acoustic logging tool comprises a transmitter and a receiver, broadcasting a pressure pulse with the transmitter into a first material, wherein the pressure pulse reflects off an interface of the first material and a pipe string as a reflected pressure pulse, recording the reflected pressure pulse with a receiver, and determining an integrity of a material using a Quintero Wellbore Index.