A wellbore tool includes a housing including a wall having an outer surface and an inner surface defining a passage. The housing has an outlet extending through the wall. A valve sleeve is axially slidably arranged in the passage. The valve sleeve includes a wall portion including a first end, a second end, an outer surface portion, an inner surface portion, an outlet portion that selectively aligns with the outlet in the housing. A locking mechanism is provided on the valve sleeve. A valve seat is axially slidably arranged at the first end of the valve sleeve. The valve seat being selectively rotationally locked to the valve sleeve by the locking mechanism.

A well tool assembly can include a well screen configured to filter fluid flow between an interior and an exterior of a tubular string, and an outflow control section that permits the fluid flow in an outward direction and prevents the fluid flow in an inward direction, the outflow control section including at least two outflow control valves arranged in series. A method can include installing a well tool assembly including a well screen, flowing a fluid from an exterior to an interior of a tubular string through the well screen and an inflow control valve of the well tool assembly, and flowing another fluid from the interior to the exterior of the tubular string through the well screen and at least one outflow control valve of the well tool assembly.

A float equipment assembly includes an inner string that provides a fluid flow path through the float equipment assembly. The float equipment assembly also includes an opening through which a fluid flowing through the inner string exits the float equipment assembly. The float equipment assembly further includes a moveable member, which when repositioned, isolates the inner string. The float equipment assembly further includes a dissolvable material that initially prevents repositioning of the moveable member, where the moveable member is repositioned after a threshold portion of the dissolvable material has dissolved.

Systems and methods for wireless telemetry in oil and gas wells use fluid pressure differentials to send signals from surface equipment to a downhole tool. More specifically, the methods and systems selectively apply fluid pressure to a tubing string and measure the resulting mechanical strain, or deformation, on a tubular of the downhole tool. The deformation may be an elastic deformation or it may be a plastic deformation with yielding of the tubular. One or more of such strains or deformations may be used to encode a digital signal that can command an action on the tool. The strain or deformation may be measured by a low-cost strain gauge.

A multi-stage object drop frac assembly that includes a fracture subassembly is configured for disposal in a well zone. The assembly includes a plurality of filtration media stages configured for disposal in the same well zone. A plurality of valves, one of the plurality of valves being associated with each of the plurality of filtration media stages is a part of the assembly and the plurality of valves are openable simultaneously in response to the same event.

Disclosed herein are downhole landing assemblies including a downhole landing assembly for an oil or gas well, downhole landing assembly may include: an upper seat cylinder capable of being coupled to an upper portion of a tubular string; a lower seat cylinder capable of being coupled to a lower portion of the tubular string, wherein the lower seat cylinder may be coupled to the upper seat cylinder; a landing seat coupled to the lower seat cylinder, the landing seat may have two inner surfaces; and a landing mandrel having two outer surfaces, wherein one outer surface of the two outer surfaces may be capable of being abutted against one inner surface of the two inner surfaces.

The present invention discloses a method for controlling a toe-end sliding sleeve in a horizontal well based on efficient decoding communication. The method comprises the following steps: forming a pressure wave signal by adjusting and controlling a pressure value in a wellbore according to a first preset encoding manner; acquiring a pressure value change signal in the wellbore, determining a reference time by using an STA/LTA method, and predicting pressure value to acquire a predicted pressure value signal curve; identifying a toe-end sliding sleeve control command in the acquired pressure wave signal by using a first preset decoding manner based on the fitness between the acquired pressure value signal curve and the predicted pressure value signal curve; and driving the toe-end sliding sleeve to perform actions according to the toe-end sliding sleeve control command. The method disclosed by the present invention is simple to operate, low in communication error rate, and aimed to solve the technical problems of complicated system of wellbore pressure test and sliding sleeve joint operation, high operation complexity, high bit error rate of pressure pulse communication, and long code element transmission time in the existing solutions in the prior art.

A wellbore completion system includes an expandable liner hanger with a post-setting fluid flow path. The system includes an expandable liner hanger that can be expanded by a running tool prior to a completion operation in a wellbore. The system also includes a circulating sleeve that can be manipulated by the running tool. The circulating sleeve can provide a return path for fluid internal to the expandable liner hanger for the completion operation that is performed subsequent to releasing the running tool from the expandable liner hanger.

A method includes monitoring fluid production at a passive ICD installed in a base pipe in a wellbore. Responsive to monitored fluid production meeting one or more predetermined criteria, a remedial sleeve component is installed for the passive ICD. The remedial sleeve component includes: one or more ports which permit throughput of fluid into the base pipe; a closing portion which selectively opens and closes the one or more ports; and one or more sealing portions, which prevent a flow of fluid into the base pipe when the one or more ports are closed. The one or more ports are selectively opened or closed responsive to one or more additional predetermined criteria. A related system includes an actuation tool which deploys into the wellbore to actuate the closing portion to selectively open and close the one or more ports.

A force setting apparatus comprises a valve manifold forming a plurality of ports and a rotary valve coupled to the valve manifold and rotatable on the valve manifold. The plurality of ports are in fluid communication with a plurality of pistons. The rotary valve is coupled to an air chamber that used to transfer low pressurized oil coming from the pistons and out of the ports. The valve is rotatable to uncover the plurality of ports and allow high pressurized oil to flow through a plurality of pistons and out of the plurality of ports. The valve is rotatable to cover the plurality of ports and allow low pressurized oil to flow through the valve and out of the air chamber.