Abstract: A self-cleaning temperature sensor comprises: a bellows coupled to a support structure; a pneumatic or hydraulic cylinder; a sensor configured to measure a temperature of a fluid and extending from the pneumatic or hydraulic cylinder, wherein the sensor comprises an exposure end configured to contact the fluid during sensing by the sensor; sensor wires connected with the sensor and extending to a control system; and a self-cleaning system comprising: a hood having walls extending radially outward a distance along a central axis wherein the hood defines a first volume; and a cleaning brush integrated with or adjacent the bottom of the support structure. In a retracted configuration, the exposure end of the sensor is positioned at a retracted position a distance from cleaning brush, and, in an extended configuration, the exposure end of the sensor extends a distance along the central axis away from the retracted position.

Abstract: A self-cleaning thermal conductivity sensor comprises: a bellows coupled to a support structure; a pneumatic or hydraulic cylinder; a sensor configured to measure a thermal conductivity of a fluid and extending from the pneumatic or hydraulic cylinder, wherein the sensor comprises an exposure end configured to contact the fluid during sensing by the thermal conductivity sensor, a temperature sensor, and a heat source; sensor wires connected with the thermal conductivity sensor and extending to a control system; a self-cleaning system comprising: a hood having walls extending radially outward and defining a volume; and a cleaning brush integrated with or adjacent the bottom of the support structure. In a retracted configuration, the exposure end of the sensor is positioned at a retracted position a distance from cleaning brush, and, in an extended configuration, the exposure end of the sensor extends a distance along the central axis away from the retracted position.

Abstract: A method for creating generated formatted data, that includes receiving, by a sequential data generator, raw data, where the raw data includes formation data at a drilling environment, processing the raw data to obtain generated recommendation data, where the generated recommendation data includes a proposed drilling location, and creating the generated formatted data, where the generated formatted data includes the generated recommendation data.

Abstract: A sag detection apparatus comprises an oven containing a sample cell supported by a cell support structure, a thermal conductivity sensor including a sensor housing, and a roller with a first end supported by a first bearing and fixedly coupled to a first end of the cell support structure and a second end supported by a second bearing and fixedly coupled to a second end of the cell support structure. Temperature sensor wires electrically connect a temperature sensor and first fixed contact via stationary contacts configured to remain fixed during rotation of the roller and rotating contacts configured to rotate with rotation of the roller. Heat source wires electrically connect a heat source and a second fixed contact via stationary contacts configured to remain fixed during rotation of the roller and rotating contacts configured to rotate with rotation of the roller.

Abstract: Gas bubble migration can be managed in liquids. In one example, a system can execute wellbore-simulation software to simulate changes in gas dissolution in a liquid over time. This may involve dividing the wellbore into segments spanning from the well surface to the downhole location, each segment spanning a respective depth increment between the well surface and the downhole location. Next, for each time, the system can determine a respective multiphase-flow regime associated with each segment of the plurality of segments based on a simulated pressure level, a simulated temperature, a simulated pipe eccentricity, and a simulated fluid velocity at the segment. The system can also determine how much of the gas is dissolved in the liquid at each segment based on the respective multiphase-flow regime at the segment. The system can display a graphical user interface representing the gas dissolution in the liquid over time.

Abstract: Methods for manufacturing lost circulation material particulates that may be for use in treating a subterranean formation are provided. In some embodiments, the methods include providing at a well-site a feed vessel that contains a liquid material, the liquid material including a monomer and an initiator; providing an injection device disposed underneath the feed vessel for directing at least a portion of the liquid material from the feed vessel to a reaction chamber, wherein the reaction chamber includes a fluid; discharging at least a portion of the liquid material from the feed vessel to the reaction chamber through an orifice disposed on the injection device; and forming LCM particulates at least in part by allowing at least a portion of the liquid material to polymerize in the fluid in the reaction chamber.

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 of determining wettability may include: measuring an electrical property of a drilling fluid; and correlating the electrical property to wettability.

Abstract: A distributed control system can be used to implement failover capabilities for control units that control well equipment during a well operation. For example, a system can include first well equipment that performs a first physical task and second well equipment that performs a second physical task different from the first physical task. Additionally, the system can include a distributed control system with a first control unit coupled to the first well equipment and a second control unit coupled to the second well equipment. Both control units may include a first control module and a second control module for automatically controlling the first physical task and the second physical task, respectively. The distributed control system can detect a failure of the second control unit and initiate a failover process in which the first control unit takes over control of the second physical task by enabling the second control module.

Abstract: Systems and methods for separating paramagnetic material in wellbore return fluid. A quadrupole magnet system is disposed along conduit so that a paramagnetic field is symmetrically formed about a central axis of the conduit. A wellbore return fluid containing paramagnetic material is directed through the conduit. The paramagnetic field drives the paramagnetic material outward towards the perimeter of the conduit, thereby concentrating fluid with little or no paramagnetic material along the central axis of the conduit. An outlet is disposed along the flow path of a portion of the concentrated fluid. In some embodiments, the outlet is positioned along the central axis, while in other embodiments, the outlet is positioned along the conduit wall. The paramagnetic material may be weighting material used to prepare drilling mud.

Abstract: Distributed artificial intelligence (AI) can be used to monitor a wellbore operation in some examples described herein. In one such example, physical equipment can be positioned at a surface of a wellsite to support a drilling operation at the wellsite. Each piece of physical equipment may include a sensor module, a processor communicatively coupled to the sensor module, and a memory. The memory can include an AI module configured to determine a condition associated with the equipment by analyzing sensor data from the sensor module using one or more machine-learning models. The memory additionally can include a warning module for causing the processor to output a warning notification based on the condition. The memory further can include a communications module for causing the processor to transmit a communication indicating the condition to a destination via a network. The communication may be different from the warning notification.

Abstract: The present disclosure relates to a pulsed-power drilling system that includes downhole mixers for restoring optimal electrical properties in drilling fluid. The downhole mixer may include a housing having an uphole and downhole end, a channel to convey the drilling fluid through the housing, and a flow restrictor including an orifice having a fixed diameter positioned in the channel between the entrance and the exit of the channel to create a pressure drop between the entrance and the exit of the channel during a drilling operation. The pressure drop increases shear stress in the drilling fluid to manage electrical properties, such as a dielectric constant, of the drilling fluid. The electrical properties of the drilling fluid facilitate the formation of an electrical arc on a drill bit of the pulsed-power drilling system.

Abstract: Fiber additives that may be useful as lost circulation materials for mitigating fluid loss and/or as bridging agents or diverting agents in subterranean treatment fluids such as drilling fluids. In some embodiments, the fiber additives include a fiber and calcium carbonate disposed on at least a portion of the outer surface of the fiber. In some embodiments, the methods include providing a treatment fluid that includes the base fluid and the fiber additives, and introducing the treatment fluid into at least a portion of a subterranean formation.

Abstract: A method and systems for performing a borehole operation with a borehole fluid that includes applying an amplitude oscillation deformation force to a sample of the borehole fluid over a period of time, measuring the deformation force from the sample, determining a storage modulus of the borehole fluid over the period of time based on the measured deformation force, determining a gel strength of the borehole fluid by correlation with the storage modulus, comparing the gel strength with a desired gel strength and if the gel strength is outside of an acceptable range of the desired gel strength, adjusting a drilling parameter, a composition of the borehole fluid, or a combination thereof, and using the borehole fluid in the borehole operation. Determining the storage modulus and the gel strength may be done using a processor and the force may be applied using a piezoelectric device.

Abstract: A system can be used to determine properties of a wellbore treatment fluid. The system can include a rotational system defining an axis of rotation and an aging cell. The aging cell can be positioned in the rotational system to rotate about the axis of rotation. The aging cell can include a housing, a sensor shaft, and a sensor. The housing can define an interior region of the aging cell to receive a wellbore treatment fluid. The sensor shaft can be at an angle from the axis of rotation and can be coupled to the interior region to transmit electronic signals about the wellbore treatment fluid. The sensor can be positioned on the sensor shaft to detect the electronic signals while the aging cell rotates about the axis of rotation, and the electronic signals can be used to determine the properties of the wellbore treatment fluid.

Abstract: A method of treating a wellbore in a subterranean formation including introducing a first fluid into a formation, wherein the first fluid comprises: a first water soluble salt and a carrier; placing a second fluid into the formation, wherein the second fluid comprises: a second water soluble salt and a carrier, wherein the first fluid and second fluid produce a solid precipitate upon contact; and allowing the solid precipitate to form in-situ in the formation. An acid may be added to the wellbore after formation of the precipitate. The method may be also used for stabilizing a wellbore during drilling, and shutting off and reopening a region in a formation.

Abstract: The disclosure provides a method for determining a composition of a fluid. The method comprises diverting a sample of a portion of the fluid to a test chamber. The method further comprises actuating a heat source disposed around the test chamber to increase the temperature within the test chamber to produce vapors from the sample of the portion of the fluid and directing the vapors from the sample of the portion of the fluid to a chemical sensor array comprising one or more chemical sensors. The method further comprises determining a composition of the vapors from the sample of portion of the fluid, wherein the composition of the vapors is associated with the composition of the fluid.

Abstract: A test apparatus can measuring particle plugging of a simulated fracture. The test apparatus can include a first test component having a first surface and a second test component having a second surface. The second test component can be positionable relative to the first test component to create a simulated fracture between the first surface and the second surface. The test apparatus can include a visualization area of at least one of the first test component or the second test component can be positioned between a fluid inlet and a fluid outlet along at least a portion of the simulated fracture.

Abstract: Methods for manufacturing lost circulation material particulates that may be for use in treating a subterranean formation are provided. In some embodiments, the methods include providing at a well-site a feed vessel that contains a liquid material, the liquid material including a monomer and an initiator; providing an injection device disposed underneath the feed vessel for directing at least a portion of the liquid material from the feed vessel to a reaction chamber, wherein the reaction chamber includes a fluid; discharging at least a portion of the liquid material from the feed vessel to the reaction chamber through an orifice disposed on the injection device; and forming LCM particulates at least in part by allowing at least a portion of the liquid material to polymerize in the fluid in the reaction chamber.

Abstract: Methods including precipitated and mined calcium carbonate lost circulation materials for use in subterranean formation operations. The precipitated calcium carbonate lost circulation materials are formed under a chosen set of precipitation conditions, including in situ in a subterranean formation. The mined calcium carbonate lost circulation materials are obtained in a desired morphological form under naturally occurring mined conditions. The precipitated and mined calcium carbonate lost circulation materials may be needle-shaped aragonite having an aspect ratio of about 1.4 to about 15.