A method for controlling a Steam Assisted Gravity Drainage (SAGD) System including injecting steam through an injector well into a formation in thermal contact with the system; automatically admitting, reducing or denying entry of fluid to a producer well through a valve based upon both of temperature and pressure. Further, a Steam Assisted Gravity Drainage (SAGD) System including a producer well having a valve that automatically admits, reduces or denies entry of fluid to a producer well through the valve based upon both of temperature and pressure.

A triggering mechanism for downhole equipment includes a housing for inserting downhole in an oilfield wellbore and associating downhole with a computer processor, a clock, at least one sensor circuit, and an electrical power source. The computer processor includes computer processing circuitry and a computer readable memory circuit. The sensor circuit senses at least a pressure parameter associated with the pressure within the oilfield wellbore downhole environment. A valve control circuit controls a valve and controls flow of control fluid to a hydromechanical device operating in association with the downhole tool within the oilfield wellbore. The valve control commands derive from real-time sampling of the downhole physical parameters to form ratio-based derivative values relating to physical parameter differences over a predetermined time span. In response to the ratio-based derivative values, the triggering mechanism generates triggering commands for flowing the control fluid to the associated hydromechanical device.

A downhole tool for coupling an electrical connection in the wellbore comprising a locator sub and a receptacle sub. The locator sub can be conveyed into the wellbore with a workstring. The receptacle sub can be coupled to a lower completion with at least one downhole tool. Workstring manipulation can insert the locator sub into the receptacle sub to provide an electrical connection between a resilient connector on the locator sub and ring connector within the receptacle sub. A fluid source fluidically connected to the electrical connection can flush out trapped wellbore fluids via a fluid pathway. The electrical connection can electrically couple to a control system at surface to the at least one downhole tool.

This disclosure includes systems and methods for actuating hydraulically-actuated devices.

A downhole tool for coupling an electrical connection in the wellbore comprising a locator sub and a receptacle sub. The locator sub can be conveyed into the wellbore with a workstring. The receptacle sub can be coupled to a lower completion with at least one downhole tool. Workstring manipulation can insert the locator sub into the receptacle sub to provide an electrical connection between a resilient connector on the locator sub and ring connector within the receptacle sub. A fluid source fluidically connected to the electrical connection can flush out trapped wellbore fluids via a fluid pathway. The electrical connection can electrically couple to a control system at surface to the at least one downhole tool.

An arming apparatus for arming a downhole tool in a wellbore casing comprising an arming member and a holding device. The arming member is disposed within an outer housing of the downhole tool and the holding device is mechanically coupled to the arming member. When a ball deployed into the wellbore casing passes through the downhole tool in a downhole direction and moves back in an uphole direction due to reverse flow, the ball engages on the holding device and functions the arming member such that a pressure actuating device in the downhole tool is armed.

A time delay apparatus for use with a downhole tool in a wellbore casing. In an exemplary embodiment, the apparatus includes an electronic circuit comprising a timer, a fusible link, a split spool device that includes a center pin held in place in a restrained position with a spool and a spring element surrounding the spool. A pressure applied to a trigger device, such as a rupture disk, activates a pressure switch and starts a timer, configured with a preset countdown time, in the electronic circuit. On expiration of the timer, the timer block of the electronic circuit generates a signal to cause breaking of the fusible link and releasing of the spring element such that the center pin of the split spool travels to a functional position and activates the downhole tool.

A down-hole tool and method for pressure testing production tubing within a borehole of a well returning the well to production, including a valve having a first valve member positioned within the tool housing and a second valve member moveable between a closed position and an open position; and a valve catcher engaged with a distal end of a rotor of the progressive cavity pump, the valve catcher for securing the second valve member in the open position with the valve catcher during rotational operation of the rotor and securing the second valve member with the valve catcher during removal of the second valve member from within the progressive cavity pump when the rotor is removed through the progressive cavity pump stator; wherein the production tubing may be pressure tested when the second valve member is in the closed position with respect to the first valve member.

An apparatus for controlling fluid flow in a borehole includes a basepipe and a flow device. The basepipe has a through-bore and defines at least one perforation. The throughbore conveys the fluid flow, and the at least one perforation communicates the through-bore outside the basepipe. The flow device comprises a barrier disposed at the at least one perforation. The barrier at least temporarily prevents fluid communication through the at least one perforation. The barrier is resistant to a pressure differential thereacross and is dissolvable over time. The barrier can include at least two elements composed of different materials, and an increase in the pressure differential across can further increase how the barrier prevents the fluid communication through the perforation.

A system for controlling flow in a wellbore can include a down-hole control module that is hydraulically coupled to multiple components of the system. The control module can include a computer, which can be preprogrammed to operate the various components in a particular sequence, and communicate confirmation or error signals to a surface location. The control module can also include a micro-hydraulic motor and pump that can that can be instructed by the computer to selectively deliver hydraulic fluid to one or more of the components of the system. The system can include isolation members such as packers, hydraulic pressure maintenance devices (PMDs), hydraulic shear joints, inflow control devices or valves (ICDs or ICVs) and a three-position valve that can be actuated by the control module without necessitating communication with a surface location.