A container device for transporting and releasing a plugging material into a well includes a longitudinal chamber for containing the plugging material, the chamber including a tubular wall extending in a longitudinal direction and at least one opening for releasing the plugging material from the chamber; a lower seal extending across the opening and closing the chamber in a closed configuration; a pressure application mechanism provided at an upper portion of the container device for pressurising at least part of the device and expelling the plugging material; and a connector provided at an upper portion of the container device for attaching the container device to an elongate member for lowering into a wellbore.

A valve assembly for connection to an opening provided in a housing of a well tool device includes a fluid communication channel, a flapper valve device, a flapper element supporting device, and a securing device. The fluid communication channel provides fluid communication from an outside of the housing to a bore provided on the inside of the housing. The flapper valve device includes a flapper element configured to be in a closed position in which the fluid communication channel is closed and an open position in which the fluid communication channel is open. The flapper element is biased to the closed position. The flapper element supporting device supports the flapper element when the flapper element is in the open position. The securing device secures the flapper valve device and the flapper element supporting device to the opening. The securing device includes a through bore forming a first part of the fluid communication channel.

A large diameter injection water well is drilled using a drilling derrick and rotary drilling techniques. After snubbing in and drilling a short distance with drilling mud, a temporary drilling header is installed below the blowout preventers. Extending downward from the temporary drilling header is a drop pipe with a valve on the lower end thereof. Drilling pipe with attachments on the lower end thereof, are lowered into the drop pipe with the valve closed. After sealing to the drilling pipe, the valve is opened and the drilling pipe and attachments are lowered to the bottom of the well for the normal drilling operation. Thereafter, the drilling pipe and attachments are removed reversing the process of retracting into the drop pipe and closing the valve before removing the seal from the drilling pipe. The repeated insertion of the drilling pipe with various attachments on the end thereof in the drilling procedure occurs without having to kill or suppress the well until the final step when removing the drop pipe. Large diameter drillable centering guides insures pilot holes are being drilled in the bottom center of the large diameter injection water well.

A well system includes a tubular string comprising a plurality of tubular segments and positioned in a wellbore drilled into a subterranean zone, and a landing sub connected to a bottom end of one of the plurality of tubular segments. The landing sub includes a landing sub central bore and a landing sub locking profile on an inner surface of the landing sub central bore. The well system also includes a valve assembly configured to be pumped down the tubular string by fluid flowing in a downhole direction through the tubular string and to land within the landing sub central bore. The valve assembly includes a main body with a valve central bore and a flapper configured to pivot between an open position and a closed position. In the closed positon the flapper seals against a flapper seat and blocks fluid from flowing in an uphole direction through the valve central bore. The valve assembly also includes a rupture disc positioned in the valve central bore and configured to rupture in response to an application of a predetermined fluid pressure and configured to block fluid from flowing through the valve central bore when in an unruptured state. The valve assembly also includes one or more valve body setting dogs positioned on an outer surface of the main body and configured to lock into the landing sub locking profile and thereby limit axial movement of the main body within the landing sub.

Apparatus and methods pertaining to an adapter mechanically connecting a wireless actuator to an SCSSV subassembly that includes an SCSSV. The adapter mechanically connects to the SCSSV subassembly so that the adapter is situated uphole of the SCSSV subassembly when set in a tubular of a wellbore. An actuating piston is carried by the adapter. The actuating piston transfers an opening force to the SCSSV in response to receipt by the adapter of pressurized fluid from the wireless actuator, thereby opening a flapper of the SCSSV.

A buoyancy assist tool and a fluid barrier in a casing string define a buoyancy chamber therebetween. The buoyancy assist tool has a housing connected in the casing string with a retaining sleeve detachably connected in the housing. The retaining sleeve is movable from a first to a second position in the housing. A flapper disk is positioned in the housing and covers an upper end of the retaining sleeve in the first position of the retaining sleeve. In the second position of the retaining sleeve the flapper disk is in a retracted position out of the flow path through the housing.

A float valve is used in a tubular having a through-bore for flow. The tubular can be a casing joint, a casing pup joint, a housing or a shell of a float collar/shoe, or other tubular element. A sleeve of drillable material is expanded inside the tubular. Sealing and/or anchor elements on the exterior of the sleeve can engage inside the tubular. Caps composed of drillable material are disposed on ends of the sleeve and have passages connected to ends of a flow tube. The flow tub is also composed of drillable material and has a bore therethrough for flow. A valve composed of drillable material is disposed in the passage of one of the caps and is configured to control the flow in the tubing through the flow tube.

A flow control system for a well includes a primary safety valve and a secondary safety valve for controlling flow from production tubing in the well. The primary safety valve includes a first valve body, a first flapper, a first control line port for receiving control fluid pressure from a control line, and a first actuator operable to open the first flapper in response to the control fluid pressure. The secondary safety valve is disposable within the valve body of the primary safety valve. The secondary safety valve also includes a second valve body, a second flapper, a second control line port for receiving control fluid pressure from the same control line as the primary safety valve when the secondary safety valve is disposed in the first valve body of the primary safety valve, and an actuator operable to open the second flapper in response to the control fluid pressure. A choke in fluid communication with the second control line port delays a closing of the second flapper relative to a closing of the first flapper in response to a decrease in the control fluid pressure.

An actuator sub for generating hydraulic pressure having a sub housing which includes (i) an outer surface, (ii) a main flow passage extending though the sub housing, and (iii) a wall space formed between the main flow passage and the housing outer surface. At least a first hydraulic tube is position in the wall space and an equalization port is configured to transmit pressure in the main flow passage to the first hydraulic tube. A drive motor driving an bi-directional hydraulic motor, are positioned in the first hydraulic tube, with the hydraulic motor being configured to output fluid to a fluid outlet of the first hydraulic tube, and the hydraulic motor, when not under power, allowing the reverse flow of fluid through the hydraulic motor. The actuator sub includes the absence of a check valve along a path carrying fluid between the hydraulic motor and the outlet of the second hydraulic tube.

The check valve positioned within a production tubing string is configured to open when a differential pressure across the check valve exceeds a specified opening differential pressure. With the check valve closed, a specified volume of gas is flowed from the production tubing string, thereby decreasing the pressure within the production tubing string from a first wellhead pressure to a second, lesser wellhead pressure. Hydrostatic pressure within the production tubing string at the check valve is increased by flowing a specified volume of water into the production tubing string above the check valve to at least partially replace the specified volume of gas. After flowing the water, a specified volume of treatment fluid is injected into the production tubing string at an injection pressure less than the first wellhead pressure and greater than the second wellhead pressure, thereby opening the check valve and flowing the treatment fluid downhole.