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 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 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 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: 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: 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 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: A mobile robot is disclosed herein. The mobile robot may include a frame, a propulsion module, a navigation module designed to navigate the mobile robot along a target pathway, and a computational module. The mobile robot may obtain a composition reading of the drilling fluid and a pressure reading of the drilling fluid. The robot may determine, using the computational module, an additive to add to a drilling fluid reservoir based on the composition reading and the pressure reading. The mobile robot may then retrieve the additive from an inventory and deposit the additive into the drilling fluid reservoir.

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: Apparatus and methods for determining a laminar-turbulent transition of a fluid are provided. For example, a measurement tool can receive a set of wellbore conditions received from a wellbore. Measurement tool parameters can be determined based on the set of wellbore conditions. The measurement tool can be set according to the measurement tool parameters such that a fluid received from the wellbore can move through the measurement tool in a laminar state. The measurement tool may be adjusted according to the measurement tool parameters such that the fluid moves in a turbulent state. The measurement tool may determine a laminar-turbulent transition region for the fluid. The measurement tool may output the laminar-turbulent transition region for use in a drilling operation in the wellbore.

Abstract: Apparatuses and methods measuring properties of drilling fluids in which the drilling fluid is contained in a structure, and a measuring device and a processor are used to measure the properties. The measuring device is immersed within the drilling fluid. The measuring device can comprise a shell defining a chamber, a weight adapted to cause the measuring device to sink through the drilling fluid, a transmitter and at least one sensor adapted to measure a property of the drilling fluid. The transmitter is adapted to transmit data representing the property to the processor.

Abstract: Apparatuses and methods measuring properties of drilling fluids in which the drilling fluid is contained in a structure, and a measuring device and a processor are used to measure the properties. The measuring device is immersed within the drilling fluid. The measuring device can comprise a shell defining a chamber, a weight adapted to cause the measuring device to sink through the drilling fluid, a transmitter and at least one sensor adapted to measure a property of the drilling fluid. The transmitter is adapted to transmit data representing the property to the processor.