Abstract: The present invention comprises a downhole unit that includes at least one plunger and that uses a power fluid to recover production fluid from a well. The downhole unit recovers production fluid and brings it to the surface of the well during both the downward and upward motion of the at least one plunger. The downhole unit can also optionally dispose of unwanted fluids in a formation.

Abstract: A control mechanism for use with a safety valve adapted to seal a wellbore is described. The control mechanism comprises at least one valve actuator for engaging with the safety valve, the at least one actuator being moveable, in use, between a valve open position in which the safety valve is open and a valve closed position, in which the safety valve is closed. The control mechanism further comprises biasing apparatus adapted to bias the at least one valve actuator to the valve closed position, wherein, in use, the at least one valve actuator extends from the safety valve up to a wellbore wellhead. In one described embodiment, the safety valve is moved between the open and closed positions by movement of the at least one valve actuator with respect to the wellbore.

Abstract: A pumping assembly includes a well head with a radial flow channel for pumped fluids. A spacer stand is secured to the well head. A hydraulic pump is provided with a housing secured to the spacer stand. The hydraulic pump has a hydraulic ram tied to a reciprocating annular piston having a central bore. When the annular piston moves in an upward direction the hydraulic ram moves toward an extended position extending from the housing. When the annular piston moves in a downward direction, the hydraulic ram moves toward a retracted position retracted within the housing. A polish rod extends up through the central bore of the annular piston and is held in position by a polish rod clamp positioned on top of the hydraulic ram. The polish rod moves with the hydraulic ram.

Abstract: A fluid injection device (38) for deployment in a well-bore to control injection of fluid into an oil reservoir, wherein the well-bore has an outer pipe (16) and an inner tube (14) which extends within the outer pipe and is connected at one end to a pressurized fluid supply above the ground. The device includes a control valve arrangement comprising: an inlet (42) for receiving the fluid from the inner tube; an outlet (56) for outputting the fluid outside the inner tube; an inlet valve (44) in a fluid path between the inlet and the outlet; and an actuator (50) associated with the inlet valve which is controllable to switch the inlet valve between its open and closed configurations, such that when the inlet valve is open, the fluid flows from the inner tube, via the inlet, fluid path and outlet to outside the inner tube. A method of controlling injection of fluid into an oil reservoir from a well-bore using such a device is also provided.

Abstract: Arrangement for the lifting of hydrocarbons in oil field wells, comprising a lifting assembly formed by a fluid collecting hose and a fluid suction tube within the well casing. The suction tube extends along the collecting hose, which has an open upper end, through which passes the upper section of the suction tube, which has an end attached to the pulling cable of the “collecting hose/suction tube” assembly.

Abstract: An electronic module for use as a subsea electronic module for an underwater fluid extraction well, wherein a local area network enables communication within the module, the local area network including a plurality of interfaces with components of the network, and wherein the interfaces comprise capacitive coupling interfaces.

Abstract: A technique facilitates actuating a variety of components in a downhole environment. The technique utilizes displacement based activation of an atmospheric actuation chamber. Activation of the atmospheric actuation chamber may be initiated via a variety of mechanisms, including manipulation of a restraining device, translation of a seal, and/or destruction of a seal. The atmospheric actuation chamber is coupled in cooperation with the corresponding downhole component to enable selective activation of the downhole component.

Abstract: A control mechanism for use with a safety valve adapted to seal a wellbore is described. The control mechanism comprises at least one valve actuator for engaging with the safety valve, the at least one actuator being moveable, in use, between a valve open position in which the safety valve is open and a valve closed position, in which the safety valve is closed. The control mechanism further comprises biasing apparatus adapted to bias the at least one valve actuator to the valve closed position, wherein, in use, the at least one valve actuator extends from the safety valve up to a wellbore wellhead. In one described embodiment, the safety valve is moved between the open and closed positions by movement of the at least one valve actuator with respect to the wellbore.

Abstract: A method, computer-readable medium and apparatus for delivering a material to a downhole location in a formation is disclosed. A device is operated at a surface location to produce an action at the downhole location related to delivery of the material to the formation. A downhole parameter is measured at the downhole location, wherein the downhole parameter is affected by the operation of the device at the surface location. The downhole parameter is measured using a sensor proximate the downhole location.

Abstract: An activation-device launching system, mounted on a cementing head, allows the deployment of a combination of darts, balls, bombs, canisters in order to activate downhole equipment, launch cementing plugs, deliver chemical products, or the like. A valve controls the flow of process fluid, and holds an activation device in place until it is time for launching. The valve also has a hollow axle through which balls may be launched into the process-fluid stream at any time.

Abstract: The invention provides a method and system for accessing a well to subterranean formations in which a first well control assembly is directly associated with the well and a second well control assembly is remotely and capable of being in fluid communication with the well.

Abstract: A polished rod for supporting a sucker rod string comprising a one piece shank with an upper end and a lower end. A first connector is formed on the upper end of the shank and a second connector is formed on the lower end of the shank. The shank has a sealing section extending from the lower end toward the upper end and the sealing section has a polished surface and a uniform cylindrical diameter substantially equal to the diameter of the upper end and the lower end of the shank. The shank further has a latching section formed between the sealing section and the upper end. The latching section of the shank has a diameter less than the diameter of the sealing section and the upper end.

Abstract: A method of wireless communication with a downhole assembly in absence of pressure pulse or hard wired communications. Tools and techniques for achieving such wireless communications are directed fluid-flow communication which may be utilized in circumstances where a completions assembly is open to the well in a pressure sense. Notably, a trigger is included with detection equipment which may be utilized to detect fluid-flow generated by surface equipment. In certain embodiments, such equipment may even be mounted exterior of completions equipment tubing through which fluid-flow communication is directed. Thus, wireless downhole communication capacity may even be provided without the need for obstructing tubing with such detection equipment.

Abstract: A method and apparatus for delivering repetitive jarring impacts to a stuck object downhole. The jarring tool is deployed on coiled tubing or other tubular well conduit, and fluid pressure is used to cycle the jar without reciprocating the well conduit at the wellhead. A hydraulic reset assembly is included. The hydraulic chamber is in fluid communication with the flow path through the tool. Thus, when the internal fluid pressure inside the tool exceeds the external pressure in the well, the fluid pressure drives the piston in the hydraulic chamber to urge the tool toward the contracted position. In this way, the reset assembly can overcome the tendency of fluid pressure to extend the tool. The reset assembly can be configured to equalize the extension pressure, to prevent undesired cocking of the tool, or to overcome the extension pressure to contract the tool for recocking the jar mechanism.

Abstract: A hydraulic pump includes a hydraulic cylinder assembly comprising a cylinder sealed by an upper head and a lower head and carrying a piston which divides the hydraulic cylinder assembly into an upper chamber and a lower chamber. A load is connected to the piston and urges it toward the lower head. A conduit connects a reversible hydraulic pump assembly in fluid flow communication with a pressurized supply of hydraulic fluid and the lower chamber for counterbalancing the load. A control system is operably associated with the reversible hydraulic pump assembly to cause hydraulic fluid to flow back and forth between the lower chamber of the hydraulic cylinder assembly and the pressurized supply of hydraulic fluid. A system is also provided to counteract leakage in the pump by adding hydraulic fluid makeup on an as needed and controlled basis.

Abstract: An apparatus and method for supplying natural gas from a well operating under vacuum conditions by extracting, storing and communicating it to a natural gas-fired piece of oil field equipment is provided. The apparatus has a pump associated with a pump jack for extracting natural gas. The apparatus communicates natural gas to a volume tank and stores it until it needed by a natural gas-fired piece of oil field equipment.

Abstract: A method and pumping unit for use with an inclined wellhead. Proper address of the wellhead is accomplished through incorporation of an elbow-shaped walking beam. The forward section of the walking beam is fabricated such that its longitudinal axis is angled to address the inclination of the wellhead. The rearward section of the walking beam and the four-bar linkage system remains unchanged relative to a prior art pump jack intended for vertical wells. This modification is a simple and effective means of addressing an angled wellhead while preserving the well-known operating characteristics of a prior art pumping unit. Torque factors, polished rod position, speed, acceleration, stroke length, and effective counterbalance remain unchanged.

Abstract: A well bore in a subterranean formation includes a signaling subsystem communicably coupled to injection tools installed in the well bore. Each injection tool controls a flow of fluid into an interval of the formation based on a state of the injection tool. Stresses in the subterranean formation are altered by creating fractures in the formation. Control signals are sent from the well bore surface through the signaling subsystem to the injection tools to modify the states of one or more of the injection tools. Fluid is injected into the stress-altered subterranean formation through the injection tools to create a fracture network in the subterranean formation. In some implementations, the state of each injection tool can be selectively and repeatedly manipulated based on signals transmitted from the well bore surface. In some implementations, stresses are modified and/or the fracture network is created along a substantial portion and/or the entire length of a horizontal well bore.

Abstract: A single or multi-bowl wellhead may be positioned in a diverter housing over the wellbore. Protrusions on the wellhead may be installed after the diverter housing is removed. The wellhead accommodates the direct connection of hydraulic lines to a hanger seated therein. An overshot running tool protects the wellhead during placement and certain operations.

Abstract: An assembly employing multiple eccentric devices about a mandrel. The assembly is configured such that at least one of the eccentric devices is adjustably orientable relative another. Thus, for example, where the devices are packers disposed about completions tubing, the adjustable orientation may be utilized to ensure enough clearance is available for downhole advancement of the assembly. As such, the assembly may remain eccentric in nature without concern over damage during positioning, particularly to a communication line running to actuatable implements of equipment coupled to the completions assembly.

Abstract: An actuator control system includes a housing assembly having at least one line therein for controlling operation of an actuator, and a modular controller attached externally to the housing assembly and interconnected to the line. A method of constructing an actuator control system includes the steps of: assembling a modular controller, the modular controller including a control valve therein for controlling operation of an actuator via a hydraulic line; testing the modular controller, including functionally testing the control valve; and then attaching the modular controller to a housing assembly having the line formed therein. Another actuator control system includes a housing assembly having at least one line therein for controlling operation of an actuator, and a modular controller attached separately to the housing assembly and interconnected to the line via a manifold of the modular controller, the manifold including a concave interface surface which receives the housing assembly therein.

Abstract: A tool that is usable in a well and may include an operator, a switch, a resilient device and an indexer. The switch may be configured to selectively communicate a first force to the operator, thereby actuating the tool. The resilient device may exert a second force. The indexer may cycle through a sequence of positions in response to alternating between the second force and a third force. The sequence includes a predetermined position configured to actuate the switch, thereby communicating the first force to the operator to actuate the tool.

Abstract: A gas lift barrier valve mandrel assembly includes a longitudinally extending tubular member that defines a production conduit and has a central longitudinal axis. A side pocket mandrel has a first pocket for accepting a gas lift barrier valve and has a first central axis. The side pocket mandrel has a second pocket for accepting a gas lift barrier valve and has a second central axis. The central axis of the production conduit, first axis and second axis are non-coaxial and are parallel to one another. A first passage fluidly connects an outside of the mandrel to an inside of the first pocket. A second passage fluidly connects the inside of the first pocket to an inside of the second pocket. A third passage fluidly connects the inside of the second pocket to the production conduit. A fourth passage connects the first pocket to the production conduit and allows insertion of a gas lift barrier into the first pocket.

Abstract: A downhole tool for incorporation in a drill pipe for selective operation of the tool from surface level when the tool is in a wellbore. The tool comprises a controller electrically powered by a power source separate from surface level, a first sensor of the controller to detect a dynamic variable of the tool in the wellbore and produce an output signal dependent thereon; a second sensor of the controller to detect a mechanical signal transmitted from an operator at surface level; a motor driven by the power source under the control of the controller when said mechanical signal is received; and an actuator driven by the motor to actuate the tool; wherein the controller switches between at least two states in response to changes in said dynamic variable, only in said second state the controller being receptive to said mechanical signal from the operator to drive the motor.

Abstract: A system that is usable with a well may include a piston, a primary control subsystem and an override subsystem. The piston actuates the downhole tool, and the primary control subsystem may be connected to at least one hydraulic line in order to move the piston in response to pressure that is communicated to the tool via the hydraulic line(s). The override subsystem may be connected to the hydraulic line(s) to override the primary control subsystem and move the piston in response to pressure communicated to the tool via the hydraulic line(s).

Abstract: A communication arrangement is disclosed for communication between a downhole line and a wellhead body having a through-hole and a valve member for closing the through-hole. The communication arrangement provides a fluid passage that extends from a wellhead body port to the downhole line thus allowing communication between the wellhead body and a safety valve or valves and/or the injection of chemicals or fluids into the well without the need to rework the valve member or disable the valve member.

Abstract: An apparatus and method for the actuation of down-hole tools are provided. The down-hole tool that may be actuated and controlled using the apparatus and method may include a reamer, an adjustable gauge stabilizer, vertical steerable tools, rotary steerable tools, by-pass valves, packers, whipstocks, down hole valves, latch or release mechanisms and/or anchor mechanisms.

Abstract: The present invention is directed towards methods and apparatus to release energy into wells using combustion of monopropellants. More specifically, this invention is directed to industrial methods to enhance the extraction of well fluids from wells by using the in-situ energy released from this inventions apparatus, methods, catalyst, and fluids blends for subterranean catalytic combustion of monopropellants.

Abstract: A well bore in a subterranean formation includes a signaling subsystem communicably coupled to injection tools installed in the well bore. Each injection tool controls a flow of fluid into an interval of the formation based on a state of the injection tool. Stresses in the subterranean formation are altered by creating fractures in the formation. Control signals are sent from the well bore surface through the signaling subsystem to the injection tools to modify the states of one or more of the injection tools. Fluid is injected into the stress-altered subterranean formation through the injection tools to create a fracture network in the subterranean formation. In some implementations, the state of each injection tool can be selectively and repeatedly manipulated based on signals transmitted from the well bore surface. In some implementations, stresses are modified and/or the fracture network is created along a substantial portion and/or the entire length of a horizontal well bore.

Abstract: An improved gas lift system for use in marginal well and small diameter production tubing is disclosed. The system uses compressed natural (produced) gas to lift formation fluids thereby enhancing produced gas. Incorporated in the system is a plurality of improved differential pressure control valves which are easier to maintain and more reliable and which provide the required lift capability with or without a standard jet pump, located at the bottom of the wellbore, to continue to lift produced fluids. The methods of use are described.

Abstract: The controller comprises housing (2) within which located is an inner mandrel (4), which is biased in an upward direction by spring (16). Balls (10) in ducts (8) are locking the inner mandrel to housing (2). At a lower end of mandrel (4) are a plurality of ports (18) which may be aligned with a set of outer ports (22). When ports (18) are to be aligned with ports (22), the drill string is rotated, generating a centrifugal force which forces balls (10) radially along ducts (8), thereby unlocking inner mandrel from outer housing. Pressure is then applied to inner duct (7), creating a pressure difference across choke (6). Under sufficient pressure, the force created is sufficient to overcome the resistive force created by spring (16), and thus the inner mandrel translates axially to bring ports (18) in alignment with ports (22), through which some or all of the drilling fluid may flow, bypassing the rest of the drill string.

Abstract: Surface controlled subsurface control valves for use in wells and methods of controlling the same. In one embodiment, a valve includes a valve body, a bore closure assembly, a mechanical linkage, a drive assembly, and a control assembly. The valve body defines a bore for fluid to flow through when the bore closure assembly is in an open position. When the bore closure assembly is in its closed position, the bore closure assembly prevents fluid from flowing through the bore. The mechanical linkage is operatively connected to the bore closure assembly and to the drive assembly. The primary control assembly determines a force to apply to the mechanical linkage based on a present operating condition of the valve and causes the drive assembly to apply the determined force to the mechanical linkage. As a result, the mechanical linkage drives the bore closure assembly.

Abstract: A system of de-watering boreholes by alternating cycles of aspiration and expulsion based on pneumatic displacement, includes a double hose to be introduced into a borehole. The double hose includes a flexible outer hose and a flexible inner hose separated by an annular space therebetween, the double hose adapted to reach a full depth of the borehole. The outer hose has an outer diameter less than a diameter of the borehole to provide an annular clearance between the borehole and the outer hose. An upper closing element is connected to an upper end of the double hose outside of the borehole, and has two outlets which permit entry and exit of air and water. A lower closing element is attached to the double hose at a lower end thereof, and includes a foot valve, a filter, and a protective element to serve as a battering ram.

Abstract: Systems, methods, and instructions encoded in a computer-readable medium can perform operations related to simulating subterranean fracture propagation. A subterranean formation model representing rock blocks of a subterranean formation is received. The subterranean formation model is used to predict a response of each rock block to one or more forces acting on the rock block during an injection treatment for the subterranean formation. The predicted responses of the rock blocks may include, for example, a fracture, a rotation, a displacement, a dilation of an existing fracture, and/or another type of response. In some implementations, an injection treatment may be designed for a subterranean formation based on the predicted response of the rock blocks.

Abstract: An actuator control system includes a housing assembly having at least one line therein for controlling operation of an actuator, and a modular controller attached externally to the housing assembly and interconnected to the line. A method of constructing an actuator control system includes the steps of: assembling a modular controller, the modular controller including a control valve therein for controlling operation of an actuator via a hydraulic line; testing the modular controller, including functionally testing the control valve; and then attaching the modular controller to a housing assembly having the line formed therein. Another actuator control system includes a housing assembly having at least one line therein for controlling operation of an actuator, and a modular controller attached separately to the housing assembly and interconnected to the line via a manifold of the modular controller, the manifold including a concave interface surface which receives the housing assembly therein.

Abstract: A method for reducing the number of control lines needed to control a plurality of downhole devices including supplying a first control line in operable communication with a plurality of devices, the plurality of devices including at least one group of devices; supplying a second control line in operable communication with said at least one group of devices; and actuating each device of the plurality of devices in said at least one group of devices simultaneously in response to a pressure event.

Abstract: The present invention relates to an arrangement for the lifting of hydrocarbons in oil field wells, comprising a lifting assembly formed by a fluid collecting hose and a fluid suction tube being lowered, filled and raised within a well casing.

Abstract: A through tubing intelligent completion including a completion string; one or more isolation seals on the completion string and having an undeployed set of dimensions smaller than one or more restrictions in a tubing string through which the completion string is deployed; and one or more interventionlessly actuable flow control devices in the completion string having a set of dimensions smaller than one or more restrictions in a tubing string through which the completion string is deployed and method.

Abstract: A system for completing water injection wells includes an injector well completion system. In an embodiment, an injector well completion system for liquid injection in a formation includes a casing string disposed in a wellbore having a tubing bore. The casing string includes a casing and a sliding sleeve. The sliding sleeve has a pressure control valve having open and closed positions, an actuator mandrel having a flow control device, and an injection pressure communication port. The open position of the pressure control valve actuates the actuator mandrel to align the flow control device and the injection pressure communication port to inject liquid from the tubing bore to the formation and generate fractures in the formation.

Abstract: A system and method are provided for direct connecting downhole control hydraulics through an oil field hanger, where the hanger is coupled to a wellhead, to hydraulic lines extending outside the wellhead. Further, the direct connection allows hydraulic system integrity with reduced contamination and leakage. Hydraulic tool ports, formed on the hanger, are coupled with hydraulic lines extending downward to a hydraulic tool. Side ports, formed in the hanger, are fluidicly coupled to the hydraulic tool ports. Hydraulic lines extending outside the wellhead are directly coupled with the side ports by accessing the side ports through access openings in the wellhead when the ports are aligned with the access openings. The system can still maintain pressure within internal spaces of the wellhead after the connection by sealing the access openings with flanges, where the hydraulic lines extend through openings in the flanges that are also sealed around the lines.

Abstract: A control mechanism for use with a safety valve adapted to seal a wellbore is described. The control mechanism comprises at least one valve actuator for engaging with the safety valve, the at least one actuator being moveable, in use, between a valve open position in which the safety valve is open and a valve closed position, in which the safety valve is closed. The control mechanism further comprises biasing apparatus adapted to bias the at least one valve actuator to the valve closed position, wherein, in use, the at least one valve actuator extends from the safety valve up to a wellbore wellhead. In one described embodiment, the safety valve is moved between the open and closed positions by movement of the at least one valve actuator with respect to the wellbore.

Abstract: A system for communicating information in a borehole between tool assemblies in a tool string includes receiving an information signal and separating a first signal that may be a power and low speed signal. A second signal is separated and demodulated from the information signal. The first signal and second signal are transmit to electronic devices that process data from an earth formation. After the first and second signals are transmit to one or more electronic devices, the signals are modulated and/or filtered and then combined into the information signal. The first signal is at one frequency and the second signal is at a different frequency. The apparatus includes a main signal line that couples to a second signal line and third signal line in the tool assembly.

Abstract: Water is removed from a natural gas well using a piston pump is driven by a power fluid that is pumped into the wellbore. The power fluid is intermixed within wellbore water and pumped out of the wellbore along with the removed water.

Abstract: A method of actuating a well tool utilizing first and second pressure sources includes the steps of: placing an source, thereby displacing a piston from a first position to a second position; and then placing another chamber in communication with the second pressure source, thereby displacing the piston to a third position. A multi-position actuator includes an operating member which displaces to operate a well tool, a first position of the operating member corresponding to a pressure source being in communication with a chamber and another pressure source being in communication with another chamber, a second position of the operating member corresponding to the same pressure source being in communication with both of the chambers, and a third position of the operating member corresponding to the pressure sources being connected to the chambers oppositely to that of the first position.

Abstract: An actuator control system includes a housing assembly having at least one line therein for controlling operation of an actuator, and a modular controller attached externally to the housing assembly and interconnected to the line. A method of constructing an actuator control system includes the steps of: assembling a modular controller, the modular controller including a control valve therein for controlling operation of an actuator via a hydraulic line; testing the modular controller, including functionally testing the control valve; and then attaching the modular controller to a housing assembly having the line formed therein. Another actuator control system includes a housing assembly having at least one line therein for controlling operation of an actuator, and a modular controller attached separately to the housing assembly and interconnected to the line via a manifold of the modular controller, the manifold including a concave interface surface which receives the housing assembly therein.

Abstract: An embodiment of a valve that is operable from one position to another position upon relief of an applied pressure includes a housing having a bore; a valve member disposed with the housing, wherein the valve member is actuated to one position in response to a certain applied pressure and actuates toward another position upon relief of the certain applied pressure; and a relief system relieving the pressure applied to the valve member when the applied pressure falls below a selected pressure level.

Abstract: An intelligent well system can service three or more zones that have gravel packed screens. A modular system features a screen and a surface controlled production valve on an internal blank pipe that internally straddles the screen. A gravel exit valve is disposed above the blank pipe and the blank pipe can optionally have a fluid loss control valve. A gravel pack/fracturing assembly can engage each module and close the fluid loss valve and gravel outlet valve on the way out of a module. Optionally the fluid loss valve can be eliminated if the gravel packing and fracturing string has the ability to power the production valve. The modules can be connected by wet connects as can the production string to make the intelligent well system functional from the surface.

Abstract: A downhole tool has housing components that are relatively movable. One of the components is supported downhole while a control line provides fluid pressure to move the other housing component relative to the supported component to put the tool in a first position. Loss of control line pressure allows the weight of tubulars bearing on the upper housing or rods to move it to put the tool in another position. The tubing weight overcomes the hydrostatic pressure in the control line even when there is no applied pressure in the control line to cause relative housing or rods movement to operate a tool. In that sense the tool can be fail safe to shut off flow, for example, on loss of control line pressure while reducing or elimination the need for a large return spring to offset hydrostatic pressure.

Abstract: An apparatus for opening and closing downhole tools, such as sliding sleeves, includes a first (opening) shifting tool connected to an end of a continuous rod, an intermediate rod connected below the first shifting tool, and a second (closing) shifting tool connected to the end of the intermediate rod. The first tool has a profile for selectively opening sleeves when moved downhole, and the second tool has a profile for selectively closing sleeves when moved uphole. Alternatively, a single tool can couple to the end of the continuous rod and can have the profiles for opening and closing sleeves. When used, the continuous rod and shifting tools are deployed downhole to a series of sliding sleeves on a tool string. Manipulated by the continuous rod and a rig at the surface, the shifting tools are used to successively open and close the sliding sleeves so that successive isolated zones of a formation can be treated with frac fluid.

Abstract: A method for controlling the electrical power delivered to a downhole system. The downhole system may include a power supply, a downhole tool, and a wire or cable connecting the downhole tool to the power supply. A resistive load, such as a motor, is included with the downhole tool. The power supplied to the downhole tool is dynamically adjustable to match the resistive load voltage and power rating. Dynamically adjusting power is accomplished by varying voltage from the power supply, varying the resistive load requirements, or a combination of both.