Abstract: A method of intervention in a failed deep-set tubing-retrievable subsurface safety valve disposed in a deepwater or ultra-deepwater subsea well uses a deep-set wireline-retrievable subsurface safety valve that may be deployed via wireline into the failed deep-set tubing-retrievable subsurface safety valve. The deep-set wireline-retrievable subsurface safety valve has a closure actuation mechanism that is disposed below the closure device. In addition, the closure actuation mechanism includes a pressure-balanced piston that is exposed to wellbore fluids on both distal ends of the piston, thereby allowing the piston to actuate the closure device in deepwater and ultra-deepwater wells with significant hydrostatic head in the control line.

Abstract: A subsurface safety valve system for a wellbore is described. The system can include a tubular housing disposed within the wellbore having a cavity running in a longitudinal direction therethrough. The system can also include an electromagnetic device configured to receive electric power to create a magnetic field, and a flapper operative to open and close the cavity in response to the electric power received by the electromagnetic device. The flapper may open in response to the electric power exceeding a first electric power value and remain open in response to the electric power exceeding a second electric power value which is lower than the first electric power value.

Abstract: An injection sleeve and apparatus for injecting fluid into a well includes a flow tube having a piston which upon fluid flow opens one or more outlet ports. The injection sleeve is adapted to include a variable orifice insert which prevents flow through the tool at a first selected pressure level until the outlet ports are in an open position, thereby protecting packing seals on either side of the outlet ports from undue wear and tear, and prolonging the life of the tool. At a second pressure level, the variable orifice insert permits flow through injection sleeve to the formation injection zones. A plurality of the sleeves may be used for sequentially injecting fluid into a plurality of injection formation zones surrounding a well. When injection fluid flow is terminated, the injection sleeves act as a dual barrier valve for preventing flow from the injection formation zones back to the well head.

Abstract: A production tubing pressure insensitive wireline retrievable safety valve includes an upper and a lower packing to create a hydraulic seal in an annulus surrounding a portion of the wireline retrievable safety valve and a hydraulic fluid intake port to receive hydraulic fluid in the annulus surrounding the wireline retrievable safety valve within the hydraulic seal from a surface. The hydraulic fluid is communicated to a piston shoulder chamber disposed below the hydraulic seal to move a power piston under actuation pressure and compress a power spring disposed within a gas chamber. A ball valve connected to the power piston moves a ball off seat when the power piston is forced down allowing fluid communication through a plurality of flow ports into a central lumen of the wireline retrievable safety valve exposed when the ball is off seat.

Abstract: A method and apparatus for completing a well that includes a subsurface barrier valve utilizes an injection valve which includes a variable orifice insert. The injection valve includes a mechanism for sensing pressure cycles that are employed during various well completion operations including pressure testing. The mechanism includes an indexing sleeve which will disable pressure functionality. Once this occurs, pressure cycling to open the barrier valve can proceed. Once the barrier valve opens, flow alone controls the injection valve during normal operations.

Abstract: A method and apparatus for controlling the flow of fluid in an injection well includes a main valve assembly having a valve and a retrievable nozzle selective lock assembly (RNSLA). The RNSLA is operable when positioned within the valve body to open the valve when fluid is pumped into the well and closes the valve when fluid flow is terminated. The RNSLA includes a replaceable orifice nozzle so that orifices of different dimensions may be used in conjunction with the valve assembly. In an alternate embodiment, the RNSLA includes a variable output nozzle assembly to maintain the valve in a protected open position without chattering over a wide range of flow rates.

Abstract: A subsurface safety valve system for a wellbore is described. The system can include a tubular housing disposed within the wellbore having a cavity running in a longitudinal direction therethrough. The system can also include an electromagnetic device configured to receive electric power to create a magnetic field, and a flapper operative to open and close the cavity in response to the electric power received by the electromagnetic device. The flapper may open in response to the electric power exceeding a first electric power value and remain open in response to the electric power exceeding a second electric power value which is lower than the first electric power value.

Abstract: A chemical injection mandrel for injecting chemicals into a Lower Tertiary well includes a chemical injector disposed on an exterior surface of a mandrel. The chemical injection mandrel connects to the production tubing such that the chemical injector portion of the chemical injection mandrel is disposed in the annulus between the production tubing and wellbore at or near the bottom of the hole. A floating production storage and offloading unit on the surface of the water may include a chemical injection pump that injects chemicals downhole via a chemical fluid line that runs in the annulus between the production tubing and the wellbore. The chemical fluid line connects to the chemical injector portion of the chemical injection mandrel and delivers chemicals to the interior passageway of the mandrel of the chemical injection mandrel where the chemicals mix with the production flow directed to the surface.

Abstract: A chemical injection mandrel for injecting chemicals into a Lower Tertiary well includes a chemical injector disposed on an exterior surface of a mandrel. The chemical injection mandrel connects to the production tubing such that the chemical injector portion of the chemical injection mandrel is disposed in the annulus between the production tubing and wellbore at or near the bottom of the hole. A floating production storage and offloading unit on the surface of the water may include a chemical injection pump that injects chemicals downhole via a chemical fluid line that runs in the annulus between the production tubing and the wellbore. The chemical fluid line connects to the chemical injector portion of the chemical injection mandrel and delivers chemicals to the interior passageway of the mandrel of the chemical injection mandrel where the chemicals mix with the production flow directed to the surface.

Abstract: A wireline retrievable injection valve for an oil or gas well has an internal valve that is initially moved to open a flapper safety valve and also opens to allow fluid flow through the valve. The internal valve includes a sleeve that opens the flapper safety valve and shields the flapper safety valve from fluid. In this manner the flapper valve is protected from being caused to “flutter” or “chatter” due to pressure variations in the fluid flow, which may damage the seat.

Abstract: A chemical injection mandrel for injecting chemicals into a Lower Tertiary well includes a chemical injector disposed on an exterior surface of a mandrel. The chemical injection mandrel connects to the production tubing such that the chemical injector portion of the chemical injection mandrel is disposed in the annulus between the production tubing and wellbore at or near the bottom of the hole. A floating production storage and offloading unit on the surface of the water may include a chemical injection pump that injects chemicals downhole via a chemical fluid line that runs in the annulus between the production tubing and the wellbore. The chemical fluid line connects to the chemical injector portion of the chemical injection mandrel and delivers chemicals to the interior passageway of the mandrel of the chemical injection mandrel where the chemicals mix with the production flow directed to the surface.

Abstract: A method and apparatus for controlling the flow of fluid in an injection well includes a main valve assembly having a valve and a retrievable nozzle selective lock assembly (RNSLA). The RNSLA is operable when positioned within the valve body to open the valve when fluid is pumped into the well and closes the valve when fluid flow is terminated. The RNSLA includes a replaceable orifice nozzle so that orifices of different dimensions may be used in conjunction with the valve assembly. In an alternate embodiment, the RNSLA includes a variable output nozzle assembly to maintain the valve in a protected open position without chattering over a wide range of flow rates.

Abstract: An injection sleeve and apparatus for injecting fluid into a well includes a flow tube having a piston which upon fluid flow opens one or more outlet ports. The injection sleeve is adapted to include a variable orifice insert which prevents flow through the tool at a first selected pressure level until the outlet ports are in an open position, thereby protecting packing seals on either side of the outlet ports from undue wear and tear, and prolonging the life of the tool. At a second pressure level, the variable orifice insert permits flow through injection sleeve to the formation injection zones. A plurality of the sleeves may be used for sequentially injecting fluid into a plurality of injection formation zones surrounding a well. When injection fluid flow is terminated, the injection sleeves act as a dual barrier valve for preventing flow from the injection formation zones back to the well head.

Abstract: A subsurface safety valve is operable to close a fluid flow path by virtue of an axially movable flow sleeve. The valve includes a recockable actuator and a latch mechanism so that the valve can be moved to a closed position without overcoming the pressure head and frictional forces currently encountered in conventional safety valves. The latch mechanism includes one or more micro pistons.

Abstract: Apparatus and method for limiting the expansion and contraction of a production tubular within a pumpjack oil well includes an anchor having a hydraulic dampening chamber and an expansion joint. A piston is attached to the tubular and position within the hydraulic dampening chamber so that axial expansion and contraction of the tubular caused by thermal and loading forces is resisted by the constrained movement of the piston within the hydraulic chamber.

Abstract: A method and apparatus for controlling the flow of fluid in an injection well includes a main valve assembly having a valve and a retrievable nozzle selective lock assembly (RNSLA). The RNSLA is operable when positioned within the valve body to open the valve when fluid is pumped into the well and closes the valve when fluid flow is terminated. The RNSLA includes a replaceable orifice nozzle so that orifices of different dimensions may be used in conjunction with the valve assembly. In an alternate embodiment, the RNSLA includes a variable output nozzle assembly to maintain the valve in a protected open position without chattering over a wide range of flow rates.

Abstract: An injection sleeve and apparatus for injecting fluid into a well includes a flow tube having a piston which upon fluid flow opens one or more outlet ports. The injection sleeve is adapted to include a variable orifice insert which prevents flow through the tool at a first selected pressure level until the outlet ports are in an open position, thereby protecting packing seals on either side of the outlet ports from undue wear and tear, and prolonging the life of the tool. At a second pressure level, the variable orifice insert permits flow through injection sleeve to the formation injection zones. A plurality of the sleeves may be used for sequentially injecting fluid into a plurality of injection formation zones surrounding a well. When injection fluid flow is terminated, the injection sleeves act as a dual barrier valve for preventing flow from the injection formation zones back to the well head.

Abstract: A wireline retrievable injection valve for an oil or gas well has an internal valve that is initially moved to open a flapper safety valve and also opens to allow fluid flow through the valve. The internal valve includes a sleeve that opens the flapper safety valve and shields the flapper safety valve from fluid. In this manner the flapper valve is protected from being caused to “flutter” or “chatter” due to pressure variations in the fluid flow, which may damage the seat.

Abstract: A wireline retrievable injection valve for an oil or gas well has an internal valve that is initially moved to open a flapper safety valve and also opens to allow fluid flow through the valve. The internal valve includes a sleeve that opens the flapper safety valve and shields the flapper safety valve from fluid. In this manner the flapper valve is protected from being caused to “flutter” or “chatter” due to pressure variations in the fluid flow, which may damage the seat.

Abstract: A method and apparatus for controlling the flow of fluid in an injection well includes a main valve assembly having a valve and a retrievable nozzle selective lock assembly (RNSLA). The RNSLA is operable when positioned within the valve body to open the valve when fluid is pumped into the well and closes the valve when fluid flow is terminated. The RNSLA includes a replaceable orifice nozzle so that orifices of different dimensions may be used in conjunction with the valve assembly. In an alternate embodiment, the RNSLA includes a variable output nozzle assembly to maintain the valve in a protected open position without chattering over a wide range of flow rates.