A fluid pulse generator can include a fluid motor and a bypass flow path in fluid communication with an inlet and an outlet, and a flow control device configured to permit flow through the bypass flow path in response to a predetermined pressure differential applied across the flow control device. A method of generating fluid pulses can include flowing a fluid through a fluid pulse generator, thereby generating fluid pulses, and then applying a predetermined pressure differential from an inlet to an outlet of the fluid pulse generator, thereby permitting flow of the fluid through the fluid pulse generator without generating the fluid pulses. A fluid pulse generation system can include a fluid pulse generator with a fluid motor, a variable flow restrictor, and a bypass flow path. A predetermined pressure differential applied across the fluid motor permits the flow of the fluid through the bypass flow path.

A tunable wellbore pulsation valve reduces drillstring friction in a wellbore. An upper valve plate and a lower valve plate, and upper valve plate orifice and lower valve plate orifice enabling throughflow. A Moineau motor rotates the upper valve plate while the lower valve plate remains stationary. Fluid flow causes a first fluid state of fluid passing through both the upper valve plate and the lower valve plate when the fluid passing causes rotation of the upper valve plate to align the upper valve plate orifice with the lower valve plate orifice. Increased flow efficiency produces more powerful fluid pressure pulsations and axial vibrations without increasing pump pressure at the surface of the wellbore, yielding increased wellbore friction reduction while expending the same or less energy at the surface pump than would be expended in the absence of the reduced turbulent and shear conditions and increased laminar conditions.

A tunable wellbore pulsation valve reduces drillstring friction in a wellbore. An upper valve plate and a lower valve plate, and upper valve plate orifice and lower valve plate orifice enabling throughflow. A Moineau motor rotates the upper valve plate while the lower valve plate remains stationary. Fluid flow causes a first fluid state of fluid passing through both the upper valve plate and the lower valve plate when the fluid passing causes rotation of the upper valve plate to align the upper valve plate orifice with the lower valve plate orifice. Increased flow efficiency produces more powerful fluid pressure pulsations and axial vibrations without increasing pump pressure at the surface of the wellbore, yielding increased wellbore friction reduction while expending the same or less energy at the surface pump than would be expended in the absence of the reduced turbulent and shear conditions and increased laminar conditions.

A system provides for the remote activation and deactivation of a downhole tool such as an agitator tool. The downhole tool uses a dart-catching section configured with a profile that engages with a corresponding key section of a dart. Different tools in the string may have different profiles, allowing darts to pass through tools to reach a tool with a matching profile further downhole. The dart includes a removable nozzle that can be detached by a object dropped from the surface, after which a second dart may be dropped to engage with the first dart to change operating parameters of the tool.

A tubing string, such as a coiled tubing or jointed tubing string, has an agitator mounted within an interior of the tubing string at an intermediate position between an uphole end and a downhole end of the tubing string. A tubing agitator is structured to be installed within a tubing string. A method includes: forming or installing a seat within an interior of a tubing string at an intermediate position between an uphole end and a downhole end of the tubing string; and conveying an agitator through the interior of the tubing string until the agitator contacts the seat. A hammer drift tool is also described.

A tubing string, such as a coiled tubing or jointed tubing string, has an agitator mounted within an interior of the tubing string at an intermediate position between an uphole end and a downhole end of the tubing string. A tubing agitator is structured to be installed within a tubing string. A method includes: forming or installing a seat within an interior of a tubing string at an intermediate position between an uphole end and a downhole end of the tubing string; and conveying an agitator through the interior of the tubing string until the agitator contacts the seat. A hammer drift tool is also described.

An automated slide drilling system (ASDS) may be used with a drilling rig system to control slide drilling. The ASDS may autonomously control slide drilling without user input during the slide drilling. The ASDS may further support a transition from rotary drilling to slide drilling to rotary drilling without user input during the transitions. The ASDS may also support user input and user notifications for various steps to enable manual or semi-manual control of slide drilling by a driller or an operator.

An estimation system includes an acquirer, an inferrer, a corrector, and an estimator. The acquirer acquires a measured value of an outer surface temperature of a pipe through which fluid flows. The inferrer infers an execution time for a removal process for deposits on an inner surface of the pipe. The corrector corrects an estimated value used for estimating a thickness of the deposits, by using the measured value of the outer surface temperature of the pipe, which is acquired within a predetermined time from an inference result of the execution time for the removal process for the deposits. The estimator estimates the thickness of the deposits based on the corrected estimated value and the measured value of the outer surface temperature of the pipe.

An estimation system includes an acquirer, an inferrer, a corrector, and an estimator. The acquirer acquires a measured value of an outer surface temperature of a pipe through which fluid flows. The inferrer infers an execution time for a removal process for deposits on an inner surface of the pipe. The corrector corrects an estimated value used for estimating a thickness of the deposits, by using the measured value of the outer surface temperature of the pipe, which is acquired within a predetermined time from an inference result of the execution time for the removal process for the deposits. The estimator estimates the thickness of the deposits based on the corrected estimated value and the measured value of the outer surface temperature of the pipe.

A fluidic agitator includes a seamless insert body having an outer enclosure wall defining an enclosed cavity and a plurality of inner channel walls arranged to define an inlet chamber, a vortex chamber, and a feedback chamber within the enclosed cavity. The inlet chamber, the vortex chamber, and the feedback chamber create a hydraulic pulse in a fluid stream received in the enclosed cavity.