Abstract: A system including a bottom hole assembly and a ram positioned below a barrier of a well and methods for deploying the same are described. The ram is configured to secure the bottom hole assembly at an end of the bottom hole assembly to secure the bottom hole assembly within the well.

Abstract: Disclosed are perturbation signaling systems and methods for use in a downhole well. Such systems can include a downhole tool configured to hang from a wellbore anchoring mechanism. The tool can have or associate with an energy harvesting system, a power management system, a sensing system, and a wireless communication system. A turbine generator can encode signals into flowing fluid through electric load and related changes in hydraulic energy, transmitting information through the fluid. A receiver station positioned at another well location can decode and or relay the signals. Signals can bypass impediments such as noise zones by inducing signals in adjacent parallel well environments such as an annulus. The receiver station can accumulate energy from repeated redundant signaling over time to enhance communication and signal resolution. An additional wireless communication system can receive and/or relay data to a remote location.

Abstract: A method for measuring the thickness of casing in a wellbore and/or analyzing the inner surface of the cased or non-cased wellbore. The method includes an positioning an untethered logging tool in a drill string, receiving the logging tool in a catcher positioned within the drill string, positioning a plurality ultrasonic transducers with the average distance between the outer surface of the plurality of transducers and an interior surface of the catcher sub being less than 0.8 mm, and moving the drill string and the logging tool toward a mouth of the borehole while transmitting acoustic waves through the catcher sub toward the wellbore casing and receiving acoustic waves back to the logging tool after the acoustic waves interact with the wellbore casing and reflect through the catcher.

Abstract: An assembly and a method for entering a lateral branch of a main wellbore through a lateral window with an assembly are described. The assembly includes an arm coupled to a body. The arm positions the body to enter the lateral branch. The assembly includes an actuator to actuate the arm relative to the body. The assembly includes a first sensor, a second sensor, and a controller. The first sensor senses a condition of the arm and transmit the condition of the arm to the controller. The second sensor senses when the assembly is located in the main wellbore or the lateral branch transmits the location to the controller. Responsive to either the first signal or the second signal, the controller actuates the arm relative to the body to position the body to enter the lateral window and determines when the assembly has entered the lateral branch.

Abstract: Downhole equipment and surface equipment communicate wirelessly with each other. A signal wirelessly transmitted at a first frequency from a downhole controller disposed within a wellbore is received at a surface location. The received signal is demodulated to a demodulated digital value. The demodulated value is added to an end of a buffer string. The buffer string is processed to determine whether the buffer string contains a message that is valid. In response to determining that the buffer string contains the message that is valid, the message is decoded. A command signal is wirelessly transmitted at a second frequency different from the first frequency to the downhole controller to adjust a state of the downhole controller.

Abstract: A method for measuring the thickness of casing in a wellbore and/or analyzing the inner surface of the cased or non-cased wellbore. The method includes an positioning an untethered logging tool in a drill string, receiving the logging tool in a catcher positioned within the drill string, positioning a plurality ultrasonic transducers with the average distance between the outer surface of the plurality of transducers and an interior surface of the catcher sub being less than 0.8 mm, and moving the drill string and the logging tool toward a mouth of the borehole while transmitting acoustic waves through the catcher sub toward the wellbore casing and receiving acoustic waves back to the logging tool after the acoustic waves interact with the wellbore casing and reflect through the catcher.

Abstract: A system includes a surface sub-system and a downhole sub-system. The surface subsystem includes a pump and a surface valve sub-assembly. The pump is configured to pump a fluid from a container, downhole into a wellbore. The surface valve sub-assembly is fluidically coupled to the pump and configured to receive a first portion of the fluid pumped by the pump. The surface valve sub-assembly includes a dump valve, a surface controller, and a return line. The surface controller is configured to adjust fluid flow through the dump valve, and the return line is configured to flow fluid from the dump valve to the container. The downhole sub-system includes a turbine-generator and a downhole controller coupled to the turbine-generator. The turbine-generator is configured to generate an output in response to receiving a second portion of the fluid pumped by the pump.

Abstract: An assembly and a method for entering a lateral branch of a main wellbore through a lateral window with an assembly are described. The assembly includes an arm coupled to a body. The arm positions the body to enter the lateral branch. The assembly includes an actuator to actuate the arm relative to the body. The assembly includes a first sensor, a second sensor, and a controller. The first sensor senses a condition of the arm and transmit the condition of the arm to the controller. The second sensor senses when the assembly is located in the main wellbore or the lateral branch transmits the location to the controller. Responsive to either the first signal or the second signal, the controller actuates the arm relative to the body to position the body to enter the lateral window and determines when the assembly has entered the lateral branch.

Abstract: Downhole equipment and surface equipment communicate wirelessly with each other. A signal wirelessly transmitted at a first frequency from a downhole controller disposed within a wellbore is received at a surface location. The received signal is demodulated to a demodulated digital value. The demodulated value is added to an end of a buffer string. The buffer string is processed to determine whether the buffer string contains a message that is valid. In response to determining that the buffer string contains the message that is valid, the message is decoded. A command signal is wirelessly transmitted at a second frequency different from the first frequency to the downhole controller to adjust a state of the downhole controller.

Abstract: A system includes a surface sub-system and a downhole sub-system. The surface subsystem includes a pump and a surface valve sub-assembly. The pump is configured to pump a fluid from a container, downhole into a wellbore. The surface valve sub-assembly is fluidically coupled to the pump and configured to receive a first portion of the fluid pumped by the pump. The surface valve sub-assembly includes a dump valve, a surface controller, and a return line. The surface controller is configured to adjust fluid flow through the dump valve, and the return line is configured to flow fluid from the dump valve to the container. The downhole sub-system includes a turbine-generator and a downhole controller coupled to the turbine-generator. The turbine-generator is configured to generate an output in response to receiving a second portion of the fluid pumped by the pump.

Abstract: Disclosed are perturbation signaling systems and methods for use in a downhole well. Such systems can include a downhole tool configured to hang from a wellbore anchoring mechanism. The tool can have or associate with an energy harvesting system, a power management system, a sensing system, and a wireless communication system. A turbine generator can encode signals into flowing fluid through electric load and related changes in hydraulic energy, transmitting information through the fluid. A receiver station positioned at another well location can decode and or relay the signals. Signals can bypass impediments such as noise zones by inducing signals in adjacent parallel well environments such as an annulus. The receiver station can accumulate energy from repeated redundant signaling over time to enhance communication and signal resolution. An additional wireless communication system can receive and/or relay data to a remote location.

Abstract: A zonal isolation assessment system includes a receiver, production tubing disposed in a wellbore, a zonal isolation assembly, and an assessment assembly. The zonal isolation assembly is fluidically coupled to the production tubing. The zonal isolation assembly includes isolation tubing that flows production fluid from the wellbore to the production tubing, a first sealing element, and a second sealing element to fluidically isolate an internal volume of the isolation tubing from an isolated annulus defined between the isolation tubing and the wall of the wellbore. The assessment assembly includes a first pressure sensor at the internal volume of the isolation tubing configured to sense a first pressure value and a second pressure sensor at the annulus and configured to sense a second pressure value. The assessment assembly transmits to the receiver the first pressure value and the second pressure value to determine the integrity of the zonal isolation assembly.

Abstract: A system including a bottom hole assembly and a ram positioned below a barrier of a well and methods for deploying the same are described. The ram is configured to secure the bottom hole assembly at an end of the bottom hole assembly to secure the bottom hole assembly within the well.

Abstract: A well tool includes a deformable liner configured to be positioned within a wellbore. The deformable liner is configured to be deformed radially. The well tool includes a first inflatable packer configured to be positioned within the deformable liner. The first inflatable packer is configured to be inflated while positioned within the deformable liner to deform the deformable liner radially. The well tool includes a second inflatable packer configured to be positioned around the deformable liner. The second inflatable packer is configured to be inflated to an inner wall of the wellbore.

Abstract: A zonal isolation assessment system includes a receiver, production tubing disposed in a wellbore, a zonal isolation assembly, and an assessment assembly. The zonal isolation assembly is fluidically coupled to the production tubing. The zonal isolation assembly includes isolation tubing that flows production fluid from the wellbore to the production tubing, a first sealing element, and a second sealing element to fluidically isolate an internal volume of the isolation tubing from an isolated annulus defined between the isolation tubing and the wall of the wellbore. The assessment assembly includes a first pressure sensor at the internal volume of the isolation tubing configured to sense a first pressure value and a second pressure sensor at the annulus and configured to sense a second pressure value. The assessment assembly transmits to the receiver the first pressure value and the second pressure value to determine the integrity of the zonal isolation assembly.

Abstract: An apparatus and methods for using and deploying the same within a subterranean zone are described. The apparatus includes a conduit and an expandable mandrel positioned within the conduit. The conduit is configured to be positioned within a subterranean zone. The conduit has an inner surface and an outer surface. The conduit defines an opening extending from the inner surface to the outer surface. At least a portion of the expandable mandrel is smaller than the opening. A longitudinal length of the expandable mandrel is longer than a longitudinal length of the opening. The expandable mandrel, when actuated, is configured to move in a radial direction with respect to the conduit, such that the portion of the expandable mandrel smaller than the opening moves through the opening and extends beyond the outer surface of the conduit.

Abstract: An example system for a well includes a tubing string including spoolable, flexible, coiled tubing to transport fluids within the well; a packer associated with the tubing string to provide an annular seal to a section of a wellbore of the well; a power generator associated with the tubing string to generate power for the system based on fluid flow within the well; a wireless communication device associated with the tubing string to exchange information with one or more components of the system; one or more sensors associated with the tubing string to sense one or more environmental conditions in the well; one or more processing devices associated with the tubing string to generate at least some of the information based on the one or more environmental conditions; and one or more inflow control valves to control a rate of fluid flow into the system.

Abstract: A system and methods of its use are described. The system includes a well tool configured to be positioned within a wellbore. The system includes a sleeve defining an inner volume. The sleeve is configured to secure at least a portion of the well tool within the inner volume while the well tool is positioned within the wellbore. The system includes a hollow member positioned within the inner volume and coupled to the well tool. The system includes a rod positioned within the inner volume and coupled to the sleeve. The rod passes through the hollow member to couple to the sleeve. The rod is configured to move the sleeve relative to the well tool in response to a pressure applied on the rod. The hollow member defines a seat configured to receive the rod to restrict movement of the sleeve relative to the well tool.

Abstract: A method for measuring the thickness of casing in a wellbore and/or analyzing the inner surface of the cased or non-cased wellbore. The method includes an positioning an untethered logging tool in a drill string, receiving the logging tool in a catcher positioned within the drill string, positioning a plurality ultrasonic transducers with the average distance between the outer surface of the plurality of transducers and an interior surface of the catcher sub being less than 0.8 mm, and moving the drill string and the logging tool toward a mouth of the borehole while transmitting acoustic waves through the catcher sub toward the wellbore casing and receiving acoustic waves back to the logging tool after the acoustic waves interact with the wellbore casing and reflect through the catcher.

Abstract: Disclosed are perturbation signaling systems and methods for use in a downhole well. Such systems can include a downhole tool configured to hang from a wellbore anchoring mechanism. The tool can have or associate with an energy harvesting system, a power management system, a sensing system, and a wireless communication system. A turbine generator can encode signals into flowing fluid through electric load and related changes in hydraulic energy, transmitting information through the fluid. A receiver station positioned at another well location can decode and or relay the signals. Signals can bypass impediments such as noise zones by inducing signals in adjacent parallel well environments such as an annulus. The receiver station can accumulate energy from repeated redundant signaling over time to enhance communication and signal resolution. An additional wireless communication system can receive and/or relay data to a remote location.