A fluid conditioning and/or treatment system is disclosed. A bell housing with a pressure relief element, for example a rupture disk, has an external shoulder to seat within a tubular. One or more filter chambers, with slots in the walls thereof, are releasably connected to the bell housing. A magnet mandrel is attached to the lowermost filter chamber. Fluids, for example drilling/completion fluids, are pumped downhole through the apparatus, and the filter chamber(s) and magnet remove solids and ferrous materials from the fluid stream. Threaded connections and connectors create a modular system, with the various elements easily changed out.

A gas control valve has a valve housing, a gas flowpath, a piston, a valve seat, a valve body, an actuating chamber, and a stack of Belleville washers. The valve housing has a gas inlet, a gas outlet, and a control fluid inlet. The gas flowpath runs from the gas inlet to the gas outlet. The piston reciprocates away from and towards a normal position. The valve body is coupled to the piston and is adapted to selectively seat on the valve seat to open and shut the gas flowpath. The actuating chamber communicates with the control fluid inlet. The washer stack is under compression to bias the piston in the normal position. The piston is responsive to fluid pressure in the actuating chamber and the washer stack so that the valve may be selectively opened and closed by sequentially increasing and decreasing pressure in the actuating chamber.

A safety valve for a wellbore can include a piston, a flapper valve, a flow tube, a series of outer magnets, and a series of inner magnets. The piston can displace the flow tube, which can operate the flapper valve. The series outer magnets can be attached to an outer wall of the piston. The series of inner magnets can be attached to a flow tube of the safety valve. The series of outer magnets and the series of inner magnets can be arranged in a non-alternating polarity pattern. The non-alternating polarity pattern can be ordered in such a way that a first force to decouple the series of inner magnets from the series of outer magnets is larger than a second force to recouple the series of inner magnets to the series of outer magnets.

A chemical injection valve can include a valve stem, flow between sections of a flow passage being prevented and permitted in respective closed and open positions of the valve stem, a resilient primary seal that prevents flow through an annular gap surrounding the valve stem in the closed position, and a bypass passage in communication with the annular gap and a flow passage section, and in communication with another flow passage section in the open position. A chemical injection system can include a chemical treatment pumped through a chemical injection valve and into an interior of a tubular string, and the chemical injection valve including a valve stem and a bypass passage extending between a flow passage section and an annulus surrounding the valve stem, the annulus being positioned longitudinally between a resilient primary seal and a metal secondary seal.

Systems and methods include a plug activated mechanical isolation device that controls fluid flow inside a tubular in a wellbore. The device includes a sleeve for coupling to the tubular, and the sleeve includes an internal bore and port for fluid flow therethrough. A channel element is positioned in the internal bore and includes an internal channel and an orifice for fluid flow between the internal channel and internal bore. The channel element is attached to the sleeve via a breakable attachment portion, and the orifice is aligned with at least one port of the sleeve. The channel element is slidable within the sleeve, upon breakage of the breakable attachment portion with a force, to move the orifice out of alignment with the port of the sleeve so that a portion of the channel element covers the port of the sleeve to block fluid flow through the port.

To deploy a capillary string through a wellhead to a downhole safety valve, a control port and a retention port are drilled in an adapter between a casing hanger and a gate valve or elsewhere. The capillary string is connected to a first port of a capillary hanger and installed through the wellhead. The capillary hanger is landed on a tubing hanger, and a side port on the capillary hanger communicates with the control port. Because the side port's location may not align with the control port, operators may need to measure how long the capillary hanger should be. A control line connects to the control port in the wellhead's side to communicate with the capillary line, and a retention rod inserts in the retention port to support the capillary hanger.

A valve system for use in a wellbore, comprising a side pocket mandrel having a main bore for alignment with a wellbore tubular and a laterally offset side pocket bore separated from the main bore by an internal wall, the laterally offset side pocket bore comprising a first receptacle for a first device and a second receptacle for a second device, the internal wall having an opening through which each of the first device and the second device is independently retrievable. There is also provided a side pocket mandrel, a hydrocarbon well and a method of operating a hydrocarbon well.

A Programmable plug system for accessing and isolating formations during hydraulic fracturing, consisting of a Programmable Plug and plurality of Sliding Sleeve Valves installed in the casing string of a wellbore, wherein Programmable Plug travels, downwards or upwards through the casing and Sliding Sleeve Valves, wherein during its travel the Programmable Plug detects and counts each sleeve using on-board sensors, electronics and software and wherein the Programmable Plug utilizes detected information to locate, activate and engage itself into the Sliding Sleeve Valves, one at a time, from the top or from the bottom, without locking in, according to programmed sequence (to open, close or bypass) stored in the on-board memory. When engaged to the Sliding Sleeve Valve from the top, the Programmable Plug opens the Sliding Sleeve Valve by applying the pump pressure from the surface, thus providing access to the zone adjacent to the Sliding Sleeve Valve while sealing and isolating the zones below the Sliding Sleeve Valve. Applying pressure in opposite direction, or pulling on by the wire line or slick line winch connected to the Programmable Plug causes the Programmable Plug to disengage itself and travel up the casing string towards next Sliding Sleeve Valve where setting, actuation, and opening is repeated for that Sliding Sleeve Valve. To close open Sliding Sleeve Valve, Programmable plug engages Sliding Sleeve from the bottom side and pushed up by well pressure from the bottom or pulled upwards by the slick line or wire line winch, thus closes the Sliding Sleeve Valve.

A technique facilitates monitoring of parameters related to a downhole operation, e.g. a water injection operation. A completion string may be deployed in a borehole with at least one water injection mandrel combined with a side pocket. A sensor tool is constructed for conveyance down through the completion string and into sealing engagement with the interior surface of the side pocket. The sensor tool comprises at least one sensor for sensing a desired parameter or parameters, e.g. pressure and/or temperature. Additionally, the sensor tool comprises a nose which is positioned to mechanically open a check valve coupled to the side pocket so as to enable monitoring of the desired parameter or parameters via the at least one sensor.

The present invention is a retrievable back pressure valve device and method of using the same that may be placed in tubing during well completion and retrieved as desired by dropping a ball down hole, which then interacts with the valve to shear the positioning points allowing for retrieval as the valve is allowed to move up the well to be removed from same.