Abstract: Techniques for controlling a trajectory of a mud motor directional drill are disclosed. A system receives one or more inputs pertaining to constraints for a wellbore in a mud motor drilling operation. The system constructs, as a function of the one or more inputs, a discretized well depth horizon. One or more binary slide and rotate commands for controlling a directional drill within the wellbore is generated based on an analysis of the discretized well depth horizon. The system controls the directional drill according to the one or more binary slide and rotate commands.

Abstract: A variety of methods and apparatus are disclosed, including for a wellbore, in one embodiment, a downhole tool having an elastomeric component including an inside portion comprising a first elastomer and an outside portion comprising a second elastomer different than the first elastomer, wherein the outside portion encloses the inside portion, and wherein the second elastomer is more chemically resistant than the first elastomer to fluids in the wellbore.

Abstract: A variety of methods and apparatus are disclosed, including, in one embodiment, resettable latch assembly for latching downhole to a mating mandrel, comprising: a mandrel; a latch collet disposed on the mandrel, wherein the latch collet is radially flexibly with respect to the mating mandrel; and an energy transfer line extending a length of the mandrel; wherein the resettable latch assembly is latchable, releasable, and relatchable to the mating mandrel with translational movement.

Abstract: Disclosed herein are systems and methods of using a coating solution such as an aromatic copolyester thermoset (ACT) to improve the wear, galling, and corrosion resistances of downhole tools and their sub-components. Aromatic copolyester thermoset may be reinforced with filler material. Further, the aromatic copolyester thermoset reinforced with filler material may be used in a borehole as a composite hollow profile, for example. In some examples, the systems may comprise a substrate for downhole applications coated with an aromatic thermosetting copolyester mixed with polytetrafluoroethylene (PTFE).

Abstract: Described herein are systems and techniques for implementing a petrophysics assistant. An example method can include receiving, by a control language model configured to perform natural language processing, a query related to one or more subject areas; based on the one or more subject areas associated with the query and a respective domain-specific knowledge of each domain-specific language model from a plurality of domain-specific language models, selecting one or more domain-specific language models from the plurality of domain-specific language models to answer the query; sending, to the one or more domain-specific language models, a request to answer the query; and generating, by the control language model, a response to the query based on one or more responses to the query received from the one or more domain-specific language models.

Abstract: A system and method for taking measurements in a formation. The system may include a quantum entangled photon source that entangles an idler particle and a probe particle, a transmitter disposed in a wellbore and connected to the quantum entangled photon source by a transmitter waveguide, a receiver disposed in the wellbore, and a carrier laser connected to the receiver by a carrier waveguide. The system may further comprise a detector connected to the carrier waveguide and an information handling system in communication with the quantum entangled photon source, the carrier laser, and the detector. The method may include broadcasting a probe particle from a transmitter into a formation, capturing the probe particle with at least one receiver after the probe particle has interacted with the formation, and measuring the probe particle during an interaction with the formation using an idler particle in a detector.

Abstract: A variety of methods and compositions are disclosed, including, in one embodiment, A friction reducer comprising: a continuous phase comprising a base oil and a secondary oil, wherein the secondary oil is different than the base oil; a discontinuous phase dispersed in the continuation phase, wherein the discontinuous phase comprises water and a water-soluble polymer, and an emulsifying surfactant.

Abstract: A method of controlling a pumping sequence of a fracturing fleet at a wellsite. A managing application executing on a computer in the control van can retrieve the pumping sequence from a local or remote storage computer. The managing application can establish an electronic communication link to receive sensor data from a plurality of fracturing units. The managing application can control the plurality of fracturing units with a stage script with multiple sequential instructions for a pumping stage of a pumping sequence while receiving one or more periodic data sets from the plurality of fracturing units wherein the data sets are indicative of the current state of the pumping stage of the pumping sequence.

Abstract: A downhole tool can include a position sensor comprising a first set of magnets and an internal slider. The downhole tool can also include a valve magnet assembly comprising a second set of magnets magnetically couplable to the first set of magnets. The second set of magnets can be positionable circumferentially around an outer diameter of the position sensor. The valve magnet assembly can be configured to move in response to a fluid valve. The valve magnet assembly can be configured to cause the internal slider of the position sensor to move in response to movement of the valve magnet assembly.

Abstract: A tubing retrievable safety valve assembly and related methods are disclosed herein. The assembly includes a primary flapper, a secondary flapper, a flow tube, and a protective sleeve. The flow tube is shiftable between a downhole position that holds the primary flapper in an open position and an uphole position that allows the primary flapper to move to a closed position. The protective sleeve, when positioned in an uphole position, holds the secondary flapper valve in an open position. The protective sleeve is shiftable to a downhole position to allow the secondary flapper to move to a closed position, for example, upon failure of the primary flapper.

Abstract: A device for coating an interior surface of a housing defining a volume comprising a plurality of reactant gas sources including reactant gases for one or more surface coating processes; first and second closures to sealingly engage with an inlet and outlet of the volume of the housing to provide an enclosed volume; a delivery line fluidically coupled to the first closure and the plurality of reactant gas sources to deliver the reactant gases to the enclosed volume; and an output line fluidically coupled to the second closure to remove one or more reactant gases, byproduct gases, or both from the enclosed volume. A method for coating an interior surface of a housing is also provided.

Abstract: Methods for improving a toughness and a strength of a stainless steel material are described herein. For example, a high strength stainless steel material can comprise at least 11 wt. % Cr, between 0.01 wt. % and 1.0 wt. % Ni, more 0 wt. % Mo, more than 0 wt. % W, more than 0 wt. % Ti, more than 0 wt. % Nb, and more than 0 wt. % V. In some examples, the high strength stainless steel material can be heat treated with at least one quench treatment and at least one tempering heat treatment. In some examples, the high strength stainless steel material can comprise between 0.01 wt. % and 0.5 wt. % Ni, no more than 0.25 wt. % Mo, no more than 0.1 wt. % W, no more than 0.1 wt. % Ti, no more than 0.1 wt. % Nb, and no more than 0.1 wt. % V.

Abstract: Disclosed herein is a liquid salt activator comprising a salt, a suspending aid, and water, wherein the salt is present in the liquid salt activator in an amount of from about 5 wt. % to about 95 wt. %, based on the total weight of the liquid salt activator. Also disclosed herein is an activated extended life slurry (ELS) composition comprising a hydraulic cement, a supplementary cementitious material, the liquid salt activator, and an aqueous fluid. The activated ELS composition can be used in a method of servicing a wellbore penetrating a subterranean formation.

Abstract: A method to perform an in-situ analysis of a downhole communication system includes generating a transmission waveform of a transmission signal, and amplifying the transmission waveform by a digital to analog converter and an amplifier that are configured to modify a property of the transmission waveform. After generating the transmission waveform, the method includes transmitting the transmission waveform to a tool of a communication system. The method further includes filtering a response waveform from the tool, the response waveform being a waveform of a signal transmitted by the tool in response to receiving the transmission waveform. The method further includes performing an in-situ analysis of the tool based on the response waveform.

Abstract: Systems and techniques are provided for determining an integrity of a seal between a formation tester and a formation during formation testing. An example method can include controlling placement of a probe of a formation tester from a wellbore and into a formation as part of a formation measurement operation performed by the formation tester in the formation; gathering first pressure measurements through a probe during a probe setting phase of the formation measurement operation; gathering second pressure measurements through the probe during a phase of the formation measurement operation after the probe setting phase; and determining an integrity of a seal between a packer of the formation tester and the formation based on a comparison of the first pressure measurements gathered during the probe setting phase and the second pressure measurements gathered during the phase of the formation measurement operation after the probe setting phase.

Abstract: A method comprises deploying, in a borehole, a downhole tool coupled to a surface system by a wireline and repeating the following operations while the downhole tool is powered on and being deployed in the borehole, obtaining surface measurements, via surface sensors, and downhole measurements, via downhole sensors, determining a DC resistance of the wireline based on the surface measurements and the downhole measurements, injecting a step signal into the wireline from the surface system, determining AC aspects of the wireline based the surface measurements and the downhole measurements at a time period after injecting the step signal into the wireline, and controlling a bus voltage of the downhole tool based on the DC resistance and the AC aspects.

Abstract: An apparatus comprises a formation tester tool to be positioned in a borehole within a formation, wherein the formation tester tool comprises a pressure sensor and a pad that is radially extendable with respect to an axis of the formation tester tool, and wherein the pressure sensor is inside the pad. The apparatus comprises a first radially extendable inner packer that is axially above the pad with respect to the axis of the formation tester tool and a second radially extendable outer packer that is axially above the first radially extendable inner packer. The apparatus comprises a third radially extendable inner packer that is axially below the pad with respect to the axis of the formation tester tool and a fourth radially extendable outer packer that is axially below the third radially extendable inner packer.

Abstract: A method of constructing an injection well for a geothermal energy system comprising determining a fracture area of an injection well with a curved wellbore by inputting the curved wellbore path, a set of formation properties, and a fracturing operation, into a fracturing model. The curved wellbore path can promote fracture interference between fracture stresses extending from the injection wellbore. A production model can determine an economic value of the production fluids produced from at least one production well by determining a contact time for the injection fluids to traverse the formation. A design process can iterate the curved wellbore path of the injection well to produce a production fluid with an economic value above a threshold value.

Abstract: An inflow control valve hammer system may include a ram disposed adjacent a valve feature, a hammer device configured to drive the ram into the valve feature, and a retention feature configured to hold the hammer device in a loaded position. The retention feature is configured to release the hammer device to impact the ram in response to a threshold force being exerted on the hammer device, and the impact drives the ram to jerk the valve feature. Additionally, the inflow control valve hammer system may include a spring and an actuator. The spring may be disposed adjacent the hammer device. The spring is configured to exert the threshold force on the hammer device in an energized state. Further, the actuator is configured to energize the spring into the energized state.

Abstract: Disclosed herein are systems and methods of determining cement integrity behind a casing string using acoustic signals in the field of well drilling and completions. Specifically, the systems and methods evaluate the interface between cement and formation and/or cement-second casing and determine the thickness of the cement. Data are processed to determine annular compression wave velocities in a cased well using a semblance method or by stacking the amplitude of the leaked A0 mode energy that has reflected from the cement-formation or cement-second casing interface. The annular compression wave velocity is necessary to convert time domain images of the annulus into radial distance domain images for better interpretation of annular conditions. A semblance method is used to determine a velocity estimate for the annulus and annular thickness. The semblance method is used for all depths and azimuths to create detailed radial distance domain images of the annulus in cased wells.