Abstract: Methods to operate an NMR tool, methods to simulate a numerically-controlled oscillator of an NMR tool in real time, and downhole NMR tools are presented. A method to operate an NMR tool includes determining a phase shift of a sinusoidal wave, determining a number of look-up tables and a number of terms of Taylor Expansions performed to obtain a value corresponding to a phase angle of the phase shift, and separating the phase angle into a first component and a second component. The method also includes obtaining a first value corresponding to the first component from the number of look-up tables, performing the number of terms of Taylor Expansions on the second component to obtain a second value corresponding to the second component, combining the first value and the second value to obtain the value of the phase angle, and generating the sinusoidal wave having the phase shift.

Abstract: Systems and methods for visualizing fluid flows in a virtual reality (VR) environment are disclosed. A digital volume image representing a reservoir formation sample is obtained from an imaging device. The digital volume is segmented by assigning hydraulic properties of the formation sample to each volume element based on image properties associated with that volume element. Fluid flow is simulated using the segmented digital volume. A vector field representing flow properties at different points along one or more flow lines through the pore space is generated. An interactive visualization of a three-dimensional (3D) virtual environment representing the formation sample with the flow line(s) is provided via a VR display. Responsive to receiving user input specifying an area of the environment to view at a selected level of detail, the specified area is rendered at the selected level of detail and a current view of the interactive visualization is updated accordingly.

Abstract: A downhole drilling system is disclosed. The downhole drilling system may include a bottom-hole assembly having a pulse-generating circuit and a switching circuit within the pulse-generating circuit, the switching circuit comprising a solid-state switch. The downhole drilling system may also include a drill bit having a first electrode and a second electrode electrically coupled to the pulse-generating circuit to receive a pulse from the pulse-generating circuit.

Abstract: A method for controlling a pump-down operation in a wellbore includes selecting a target value for downhole tension of a support cable and a recommended job speed to convey a wireline tool string down a section of the wellbore, generating a line speed signal for controlling a line speed of the support cable and a pumprate signal to control a pumprate of a hydraulic fluid in the wellbore, determining a first error between the target value for downhole tension and a measured value of the downhole tension, determining a second error between the recommended job speed and an actual line speed, and maintaining the target value for the downhole tension by simultaneously controlling the line speed and the pumprate using a value for the line speed signal and a value for the pumprate signal generated based on the first and second errors.

Abstract: Systems and methods are disclosed for controlling a downhole tool by encoding a tool control signal in a fluid flow and obtaining a temperature response downhole. In an example, a system for controlling a downhole tool includes a signal transmitter, a signal receiver, and a controller. The signal transmitter is uphole of the tool to be controlled (e.g., at surface) and encodes the tool control signal by varying one or more fluid flow parameters of a fluid flow down a well. The signal receiver is positionable in the well in fluid communication with the fluid flow. The signal receiver detects a temperature response in the fluid flow resulting from varying the one or more fluid flow parameters. A controller controls the downhole tool according to the temperature response.

Abstract: In general, in one aspect, embodiments relate to a method that includes disposing a bottom hole assembly (BHA) into a wellbore at a depth, where the BHA includes at least one transmitter configured to transmit an acoustic waveform into at least a casing, and at least one receiver. Herein the method may further comprise recording one or more casing waveforms that originate from within or behind the casing, calculating at least two or more downhole parameters with the one or more casing waveforms, calculating a correlation coefficient between the at least two or more downhole parameters, and forming a cement bond log based at least in part on the correlation coefficient.

Abstract: A cement composition including a hydraulic cement material, a latent-hydraulic cement material, and a non-hydraulic cement material. Also provided is a method including combining, at a jobsite, the cement composition comprising the hydraulic cement material, the latent-hydraulic cement material, and the non-hydraulic cement material with water to provide a cement slurry, and allowing the cement slurry to harden in the presence of carbon dioxide (CO2) to provide a hardened cement.

Abstract: A stabilizer for use in a wellbore may include a downhole tubular configured to couple to a downhole conveyance in a wellbore, as well as two or more helical blades extending radially outward from the downhole tubular. The two or more helical blades are oriented about the downhole tubular to form respective flow paths between adjacent blades. Further, each blade of the two or more helical blades may include a line-of-sight face and a gauge ramp. The line-of-sight face is formed adjacent a leading inner blade wall of the blade at a lower end of the blade and is angularly offset from the leading inner blade wall. The gauge ramp extends from an outer surface of the downhole tubular toward an outer blade surface of the blade proximate the lower end of the blade.

Abstract: A system is provided including a coiled tubing reel apparatus including a reel drum for storing a coiled tubing string spooled on the reel drum and a hydraulic reel drive motor that controls rotation of the reel drum. The system further includes a reel controller that determines an estimated reel back tension for a portion of the coiled tubing string between the reel apparatus and the injector based on a set of parameters related to a coiled tubing operation. The reel controller determines a target reel back tension to be applied to the portion of the coiled tubing string by adjusting the estimated reel back tension based on a historical job dataset. The reel controller then determines and sets a target hydraulic pressure of the reel drive motor to achieve the target reel back tension in the portion of the coiled tubing string.

Abstract: Systems and methods are provided for determining the end of a reverse cementing operation based on one or more pressure measurements. In some aspects, a cement composition can be delivered to an annulus formed between a casing and a wellbore for reverse cementing the casing. In some cases, a determination that the cement composition has reached a shoe joint at a bottom portion of the casing can be based on a threshold change in a pressure measurement obtained while delivering the cement composition. In some instances, a trigger can be initiated for closing the shoe joint after determining that the cement composition has reached the shoe joint.

Abstract: A method and system for visualizing data to detect a collar. A method may comprise disposing an electromagnetic logging tool downhole; emitting an electromagnetic field from the transmitter; energizing a casing with the electromagnetic field to produce an eddy current; recording the eddy current from the casing with the receiver; creating a variable-density-log from the recorded eddy current; selecting a wrapping period for the variable-density-log; creating a wrapped-variable-density-log from the variable-density-log using the wrapping period; and determining at least one collar location and a pipe index with the wrapped-variable-density-log. A system for to detect a collar may comprise an electromagnetic logging tool. The electromagnetic logging tool may comprise a transmitter and a receiver, wherein the transmitter and the receiver may be a coil. The system may further comprise an information handling system.

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: A composition including a particulate, water, and a suspension aid comprising graphene, wherein the graphene comprises bioderived renewable graphene (BRG) and wherein the particulate is suspended in the composition. Methods of making and using the composition are also provided.

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 method for estimating a pipe property may include disposing an electromagnetic (EM) logging tool in a wellbore. The EM logging tool may comprise a transmitter disposed on the EM logging tool and a receiver disposed on the EM logging tool. The method may further include transmitting an electromagnetic field from the transmitter into a tubular string to energize the tubular string with the electromagnetic field thereby producing an eddy current that emanates from the tubular string. The method may further include measuring the eddy current in the tubular string with the receiver on at least one channel to obtain one or more measurements from the EM logging tool. The method may further include forming an EM log from the one or more measurements, forming a relationship between a set of one or more previously analyzed measurements and at least one pipe property, and estimating the at least one pipe property from the formed relationship and the one or more measurements from the EM logging tool.

Abstract: Methods and systems for determining one or more ion components. The method may include disposing a fluid sampling tool into a wellbore wherein the fluid sampling tool includes at least one probe to fluidly connect the fluid sampling tool to a formation in the wellbore, and at least one passageway that passes through the at least one probe and into the fluid sampling tool. The method may further comprise drawing a formation fluid, as a fluid sample, through the at least one probe and through the at least one passageway, and analyzing the fluid sample in the fluid sampling tool for one or more ion components.

Abstract: A method for expanding a two-stage expandable liner hanger includes expanding a first section of an expandable tubular having the first section and a second section. The first section includes one or more anchoring ribs. The method further includes expanding the second section of the expandable tubular after cement is pumped into the expandable tubular.

Abstract: Introduced herein are a dimensionless relationship between a volumetric flow rate, a head and a kinematic viscosity in a pump operation and a method that uses the dimensionless relationship to predict a viscous performance of a pump from water performance characteristics. Using the introduced dimensionless relationship, which is called Ketan's viscous head number, the introduced method determines a viscous head correlation that allows the prediction of the pump performance to be made accurately at any given speed, flow rate and viscosity. The introduced Ketan's viscous head number and method thus allow a prediction of a pump performance in a viscous application to be made from water performance characteristics without physically testing the pump in the viscous application.

Abstract: A well system incorporates electrically conductive mesh providing robust, reliable electrical communication pathways along portions of tubular equipment. An example system comprises a tubular string disposed in a wellbore, such as a multilateral wellbore. The tubular string defines an internal fluid flow path for conveying fluids to or from a surface of a wellsite. The tubular string also includes a plurality of well components with tubular component bodies arranged along the tubular string. An electrical network along the tubular string interconnects the well components. The electrical network comprising a transmission path defined at least in part by a mesh sleeve disposed along the tubular string around the internal fluid flow path.

Abstract: Certain embodiments of the present application relate to a variable frequency drive (VFD) cabin for a pump configuration including a mobile trailer on which the VFD cabin is to be mounted. The VFD cabin generally includes a medium-voltage VFD and a ventilation system. In certain embodiments, the ventilation system is configured to generate an overpressure condition within the cabin to discourage the entry of dust and debris into the cabin. In certain embodiments, one or more components of the medium-voltage VFD are coupled to the floor of the cabin via a vibration damping system. In certain embodiments, the VFD cabin may be directly coupled to a chassis of the mobile trailer without an intervening suspension being provided between the VFD cabin and the chassis.