Abstract: Provided are wellbore treatment fluids and methods to introduce these treatment fluids in a subterranean formation. The treatment fluids include a diverter material and an aqueous carrier fluid. Further, the diverter material comprises a composite material of a polyvinyl alcohol and a plasticizer. The diverter material includes particles having a particle size distribution of about 2 to about 10 U.S. mesh and an aspect ratio of 20:1 or less. The treatment fluid is introduced into a permeable zone of a subterranean formation, wherein the permeable zone is part of a wellbore that is permeated or penetrated by fractures and fissures. The diverter material diverts at least partially the treatment fluid to a different portion of the subterranean formation.

Abstract: Temperature data collected from a distributed temperature sensing system may be used to prepare a temporal thermal profile of the wellbore. The temporal thermal profile may be used to determine a generalized heat transfer coefficient (k) and/or a generalized geothermal profile (Tae). The temporal thermal profile and the generalized heat transfer coefficient (k) and/or the generalized geothermal profile (Tae) may be used to estimate thermal properties of a wellbore, such as well as fluid and flow characteristics. A heat of hydration index may also be determined based on the temporal thermal profile.

Abstract: A downhole tool can be used as a fill valve to circulate a fluid, such as a spacer fluid, through the tool. The tool can include a top and bottom flapper valve and an inner and outer sliding sleeve. The sliding sleeves can be shifted together to allow the top flapper valve to close. Continued shifting of the inner sleeve can cause the bottom flapper valve to close. A cementing operation can then be performed through the tool. Sealing elements can be located between the outside of the inner sleeve and inside of the outer sleeve. Sealing elements can also be located between the outside of the outer sleeve and the inside of a tool mandrel. The sealing elements can prevent debris from becoming lodged within the tool.

Abstract: A wellbore anchoring device having an adjustable injection valve is disclosed. The anchoring device can include the adjustable injection valve and a spring. The spring can be positioned adjacent to the adjustable injection valve. The spring can include an initial pressure setting that is adjustable prior to the anchoring device being positioned in a wellbore to adjust a cracking pressure of the adjustable injection valve.

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: Injection into a subterranean formation is optimized using a computation model to optimize injection. An optimization objective is to maximize the cumulative fluid mass rates injection that span over the remaining life of the field, while maintaining a dense or supercritical phase and operating within the equipment operational parameters. The phase at each location may be determined based on pressure and temperature, and flow is dynamically adjusted to maintain a phase having at least a threshold density of the carbon dioxide injected at each injection location.

Abstract: Systems and techniques are described for a fluid diode. In some examples, a fluid diode can include a first fluid path for a first flow of fluid to traverse the fluid diode via a first flow direction and a second fluid path for a second flow of fluid to traverse the fluid diode via a second flow direction. The first flow direction can be associated with a first pressure drop and the second flow direction can be associated with a second pressure drop that is different than the first pressure drop. Moreover, the first fluid path and the second fluid path can be configured to remain open to the first flow and the second flow in the first flow direction and the second flow direction.

Abstract: A method of cementing may include preparing a cement slurry by mixing at least water and a cement dry blend, wherein the cement dry blend comprises a cement and an activated pozzolan; and introducing the cement slurry into a wellbore penetrating a subterranean formation; and allowing the cement slurry to set to form a hardened mass.

Abstract: Aspects of the subject technology relate to systems and methods for identifying the quality of cement bonding of an exterior surface of a wellbore casing to an Earth formation. Methods of the present disclosure may allow for bond indexes to be identified in real-time as a cementing operation is performed even when tools that perform the cementing operation generate acoustic noise that interfere with measurements used to evaluate cement bonding quality. These methods may include transmitting acoustic signals, receiving acoustic signals, filtering the received acoustic signals, identifying magnitude and attenuation values to associate with the received acoustic signals, and comparing trends in the magnitudes with the identified attenuation values. These methods may also include correcting attenuation values associated with measured data based on a set of correction rules such that bond indexes can be identified. Such correction rules may be associated with data generated by a computer model.

Abstract: A microsampling device for taking fluid samples in a wellbore. The microsampling device may comprise a microsampling tube in which one or more microsamplers disposed in the microsampling tube. Additionally, the microsampling device may comprise a fluid flow line connected to the microsampling tube in which a fluid sample traverses and a secondary fluid flow line in which at least a part of the fluid sample may traverse from the microsampling tube through the secondary fluid flow line and into a wellbore.

Abstract: According to various aspects of the subject technology, a tool collar is provided. The tool collar may include a recessed portion comprising a component segment and a threaded segment, a pressure sleeve covering the recessed portion, and a threaded component mated to the threaded segment and configured to compress the pressure sleeve against a shoulder of a downhole tool. According to some aspects, a downhole tool is provided. The downhole tool may include a recessed portion comprising a component segment and a threaded segment, an unrecessed portion comprising a shoulder, a pressure sleeve covering the recessed portion of the downhole tool, and a threaded component mated to the threaded segment and configured to compress the pressure sleeve against the shoulder of the unrecessed portion.

Abstract: A pump system for pumping production fluids from a wellbore or pumping well treatment fluids into a wellbore comprising: an axial flux electric motor; a seal section coupled to the axial flux motor; a pump intake coupled to the seal section; a pump coupled to the pump intake, and a fluid discharge coupled to the pump. The torque capacity axial flux motor may be modified without removing the axial flux motor from the pump.

Abstract: A pump system for pumping production fluids from a wellbore or pumping well treatment fluids into a wellbore comprising: an axial flux electric motor; a seal section coupled to the axial flux motor; a pump intake coupled to the seal section; a pump coupled to the pump intake, and a fluid discharge coupled to the pump. The torque capacity axial flux motor may be modified without removing the axial flux motor from the pump.

Abstract: A method for controlling a rotary steerable system (RSS) may comprise disposing the RSS into a borehole, storing a curvature for the borehole into an information handling system, storing one or more steering commands in the information handling system, taking a first attitude measurement at a first sensor and a second sensor disposed on the RSS at a first location in the borehole, and calculating a first relative attitude from the first attitude measurement at the first sensor and the second sensor. The method may further comprise taking a second attitude measurement at the first sensor and the second sensor disposed on the RSS at the second location in the borehole, calculating a second relative attitude from the second attitude measurement at the first sensor and the second sensor, and comparing the first relative attitude to the second relative attitude to find a difference.

Abstract: In accordance with presently disclosed embodiments, a hybrid drive system that uses multiple sources of mechanical energy to drive a pump is provided. The hybrid drive system may include a first mover for generating first mechanical energy, a pump, a drivetrain for providing first mechanical energy from the first mover to the pump, and a second mover within the drivetrain to generate and provide second mechanical energy to the pump. The multiple sources of mechanical energy may provide flexibility with respect to system design and allow for alternative sources of fuel and energy to be used to drive pumping systems. This may reduce the total diesel fuel consumption necessary to perform a well stimulation operation as well as provide for configurations in which diesel engines may be excluded from the pumping process in favor of alternative energy sources that typically do not have sufficient torque capacity to power a pump.

Abstract: A method and system for resistivity imaging may comprise disposing a downhole tool into a borehole, wherein the downhole tool comprises a pad and a plurality of electrodes disposed on the pad, taking an impedance measurement with the plurality of electrodes, applying a correction to the measured impedance by using a relaxation constant of the measured impedance to find a corrected impedance for each electrode of the plurality of electrodes, and constructing an image from the corrected impedance, wherein the image maps formation impedance. The system for resistivity imaging may comprise a downhole tool, a conveyance for disposing the downhole tool in a borehole, and an information handling system. The downhole tool may further comprise an arm and a pad wherein the pad comprises a plurality of electrodes and at least one return electrode.

Abstract: Methods and system involving well control. In some embodiments, the system includes an injection spool coupled to a subsea wellhead including an inlet, a manifold in fluid communication with the inlet of the injection spool for mixing one or more components of a well control treatment composition, a first container for storing natural gas in fluid communication with the manifold, and a second container for storing nitrogen in fluid communication with the manifold.

Abstract: A borehole imaging tool may include a plurality of resonator antennas for taking one or more downhole measurements disposed on a supporting structure of the borehole imaging tool. Additionally, each of the plurality of resonator antennas are separated into two or more groups of resonator antennas and each of the two or more groups of resonator antennas operate at a resonance frequency different from one another.

Abstract: Systems and methods to determine a characteristic of a drilling fluid are presented. A method to determine a characteristic of a drilling fluid includes obtaining a measurement of a mud density of a drilling fluid formed from a mixture of a plurality of components. The method also includes obtaining a measurement of a thermal conductivity of the drilling fluid and determining an error function of a calculation of characteristics of the drilling fluid, where the error function is indicative of a threshold difference between the calculation of the characteristics of the drilling fluid and the characteristics of the drilling fluid obtained from retort data of a fluid distillation process. The method further includes determining, based on the error function, an oil water ratio of the drilling fluid and an average specific gravity of the drilling fluid.

Abstract: A method for identifying a collar using machine learning may include acquiring one or more measurements from one or more depth points within a wellbore including a tubular string, training a machine learning model using a training dataset to create a trained machine learning model, and identifying at least one hyperparameter using the trained machine learning model. The method may further include creating a synthetic model, wherein the synthetic model is defined by one or more pipe attributes, minimizing a mismatch between the one or more measurements and the synthetic model utilizing the at least one hyperparameter, updating the synthetic model to form an updated synthetic model, and repeating the minimizing the mismatch with the updated synthetic model until a threshold is met.