A crossover tool for use in a wellbore includes: a tubular housing having a bypass port; a mandrel having a bore therethrough and a mandrel port in fluid communication with the mandrel bore, the mandrel movable relative to the tubular housing between a first position where the mandrel port is isolated from the bypass port and a second position where the mandrel port is aligned with the bypass port; and an actuator operable to move the mandrel between the first position and the second position. The actuator includes a first piston connected to the mandrel and a second piston operable in response to the first piston.

A system for conditioning a gas includes an inlet configured to receive the gas from a gas source. The system also includes a strainer downstream from the inlet. The strainer is configured to remove debris from the gas. The system also includes a first flowpath downstream from the strainer. The first flowpath includes a first pressure regulator that is configured to regulate a pressure of the gas by a first amount. The system also includes a second flowpath downstream from the strainer. The first and second flowpaths are parallel. The second flowpath includes a second pressure regulator that is configured to regulate the pressure of the gas by a second amount. The system also includes one or more flowpath valves downstream from the strainer and upstream from the first pressure regulator, the second pressure regulator, or both.

A pressure responsive downhole tool comprises a power piston pressure relief valve that is selectively activated and deactivated to allow pressure-related operations to be conducted. The pressure relief valve will not open until the power piston is activated, which also requires the operating element (ball valve, for example) to be opened, thereby avoided situations in which the ball valve is inadvertently placed in the Lock Open position.

Optical fiber connections and their applications in downhole assemblies are described herein. The downhole assembly includes a well completion element with an end that couples with a corresponding well completion element. An optical fiber extends along at least a portion of the well completion element and transmits an optical signal using a first mode. The well completion element includes an optical fiber connector that is coupled to the optical fiber. The connector also includes a mode converter that receives the optical signal from the optical fiber and converts the optical signal from the first mode to a second larger mode. This second larger mode may be more robustly communicated to a corresponding optical fiber connector affixed to the corresponding well completion element.

A technique facilitates control over fluid flow via controlled operation of an injection valve. The technique enables control over operation of the injection valve in a variety of subsurface applications. The injection valve comprises a flapper which may be selectively shifted to and held in an open position. Depending on the operational configuration of the injection valve, the flapper may be shifted to the open position via fluid flow along a primary flow passage. However, the injection valve also may be shifted to the open position via a separate actuator controllable via pressure applied independently of fluid flow along the primary flow passage.

A well tool device (1) comprising a housing (10) having a through channel (11) with a first end (11a) and a second end (11b), said housing (10) further comprises a breakable ball seat (15), wherein a drop ball (17) received in the ball seat (15) partially or fully closes fluid communication in the through channel (11) of the housing (10). The breakable ball seat (15) is made of brittle and/or tempered glass, wherein the ball seat (15) is broken by a pressure build up in the housing (10) forcing the ball seat (15) against one or more disintegrating means (16), said disintegrating means (16) are provided as inside protrusions in the through channel (11).

A toe valve (1) comprising; a housing (200) having an interior and exterior; a sliding sleeve (8); a counter mechanism (2) comprising a cylinder, a ratchet piston (11, 27) with first and second ends, and a ratchet shaft (14, 28) connected to the second end; a trigger assembly (3) comprising a trigger housing, and a release piston (19), wherein the trigger assembly (3) is arranged between the counter mechanism (2) and the sliding sleeve (8), and wherein the release piston (19) is configured to activate the sliding sleeve (8), and the ratchet shaft (14, 28) is configured to activate the release piston (19), wherein the toe valve (1) further comprises; a closed chamber (15) enclosing the ratchet shaft (14, 28) and defined at least partly by the cylinder comprising a chamber fluid with a chamber pressure (P2); an inlet pressure port (6) configured to be in communication with a wellbore fluid with a wellbore pressure (P1), and wherein the first end of the ratchet piston (11, 27) is in fluid communication with the inlet pressure port (6), wherein the ratchet piston (11, 27) is configured to move towards the trigger assembly (3) to a new position and compress the chamber fluid when the wellbore pressure (P1) is larger than the chamber pressure (P2); a retaining mechanism (29) configured to retain the ratchet shaft (14, 28) in the new position; and a valve mechanism interconnecting the first and second ends of the ratchet piston (11, 27) and configured for equalizing the pressure across the ratchet piston (11, 27).

A production tubing is disposed in a wellbore. Hydrocarbons entrapped in a subterranean zone enter the wellbore. Multiple valves are disposed in the production tubing at respective multiple tubing locations. The multiple valves divide the production tubing into multiple stages. A presence of hydrocarbons in a first stage terminating at a first valve is determined and gas is injected into the first stage causing the hydrocarbons in the first stage to flow uphole through the first valve into a second stage uphole of the first stage. It is determined that the second stage is filled with the hydrocarbons and injection of the gas into the first stage is ceased. Multiple side chambers are disposed in the respective multiple stages. Determining the presence of hydrocarbons in the first stage incudes detecting a fluidic level of the hydrocarbons inside the first side chamber.

The present invention applies to flowing wells. Within a flowing well, production tubing moves fluid upward under immense pressures and is greatly exposed to damage, either accidental, or intentional. Recently, there is increased concern in protecting our production wells from damage, either natural or man-made. The present invention is designed to address the problems of controlling hydrocarbon, and fluid flow, through production tubing after the production tubing is compromised by penetration or severance.

A technique facilitates control over at least one flow control assembly position to control fluid with respect to a tubing string. The flow control assembly is disposed along the tubing string and comprises a flow control valve and a motor to control the operational position of the flow control valve. The flow control valve may comprise a plunger and a seal system to provide a seal between the plunger and a surrounding structure. Additionally, the flow control valve comprises a pressure balanced system. The pressure balanced system serves to balance pressure acting on the plunger such that the motor is able to move the plunger by simply overcoming friction of the seal system without overcoming a pressure differential otherwise acting on the plunger.