Abstract: A gas-lift well having a controllable gas-lift valve is provided. The well uses the tubing and casing to communicate with and power the controllable valve from the surface. Induction chokes at the surface and downhole electrically isolate the tubing from the casing. A high band-width, adaptable communication system is used to communicate between the controllable valve and the surface. Additional sensors, such as pressure, temperature, and acoustic sensors, may be provided downhole to more accurately assess downhole conditions. The controllable valve is varied opened or closed, depending on downhole conditions, oil production, gas usage and availability, to optimize production and assist in unloading. While conventional, bellows-type, gas-lift valves frequently fail and leak—often undetected—the controllable valve hereof permits known precise operation and concomitant control of the gas-lift well.

Abstract: A well pump device (1), especially for use in connection with the recovery of hydrocarbons, wherein the pump (1) is carried to a predetermined position within a well pipe (10). The pump (1) is provided with an external seal (8) which is arranged to prevent fluid from flowing from the pressure side of the pump (1) past the pump (1) to the suction side thereof.

Abstract: “Well equipment transporting well fluid from a gassy well. A conduit is hung and sealed inside a string of casing, forcing the gas and well fluid to flow into the conduit. A gas separator and a series of flow controls and valves are mounted into and run with the conduit. A pump assembly is hung and sealed into the conduit for pumping well fluid to the surface. The pump assembly is lowered and retrieved from the conduit on tubing. The pump may be located below the motor, or above the motor.

Abstract: The present inventions contemplate an improved well tool actuator and method that does not require more expensive downhole equipment and can be utilized with limited actuation pressures. According to the improved well tool actuator and method of the present inventions, a fluid pressure intensifier is placed in the well and coupled to the downhole device to be manipulated. By using a fluid pressure intensifier the actuation pressure can be increased to a pressure sufficient to operate or manipulate the downhole device without the necessity of increasing the tubing pressure. According to the present invention the actuation pressures supplied by the intensifier can exceed the safe operating rated pressures of the well tubing and equipment. The well tool actuators of the present invention are self-contained in that they are powered from the tubing fluid pressure itself without a high-pressure hydraulic or electrical connection to the surface.

Abstract: An auto-cycling plunger including a hollow, longitudinally extending body and at least one first directional outer seal disposed on an exterior surface of the body for creating a seal between the body and a well bore. A portion of the seal is spread resiliently outwardly from the body with an applied pressure, thereby increasing the degree of sealing. The plunger also includes a valve stem including a valve member. The valve stem extends through the body and has actuable ends extending from the body. The valve stem includes an actuating head external to and proximal a first end of the body, the head being larger than the internal diameter of the first end of the body. The valve stem can be shuttled between an open position and a closed position. In the open position, the valve member is longitudinally spaced from a valve seat on the body to allow fluid flow through the body. In the closed position, the valve member is seated on the valve seat, thereby sealing the body and preventing fluid flow therethrough.

Abstract: A hydraulic submersible rotary pump and drive assembly is deployed and recovered through production tubing or casing using metal hydraulic tubing lines. The assembly is used in conventional oil and gas well bores, but is particularly advantageous in slant or horizontal applications for artificial fluid lift or water injection. It eliminates mechanical drive shafts running from surface, and allows rotary pumps to be changed without pulling the production tubing. The torque neutralizing drive assembly incorporates a ported connector sub to attach a submersible hydraulic drive motor to a submersible rotary production pump, a conventional pump seating nipple in the production tubing, and a seating cup assembly on the drive to seal the pump discharge from the pump suction within the tubing. Alternately, the assembly is used with a pack-off assembly to seal against a production casing or open hole when it is desirable not to use production tubing.

Abstract: A method of pumping well fluid from a well having casing with perforations includes connecting an electrical motor to a lower end of a pump and securing the pump to tubing. A restrictor is mounted to the tubing above the pump, the restrictor having a restrictor passage. The well annulus contains a well fluid with a static level under static conditions. When the motor is started to cause the pump to operate, downward flow of well fluid contained in the well annulus flows through the restrictor passage. This reduces the amount of downward flow to increase well fluid flow through the perforations.

Abstract: A plunger for use in downhole tubulars in wells which produce fluids and/or gases under variable pressure. The plunger is slidingly engageable within the tubulars and capable of movement up and down the tubulars, and has a jacket comprised of segments mounted about a core which have sealing, holding, and lifting capabilities. An inner turbulent or labyrinth-type seal is accomplished by circumferential grooves on the core and/or fingers which project inwardly from the underside of the segments. When the pressure inside the tubulars above the plunger is reduced, the plunger and fluids move upwardly to the surface.

Abstract: A downhole gas compression system is adapted for location in a bore of a natural gas-producing well (10), the system comprising an axial flow compressor (32) and a gas-filled electric drive motor (30). The motor drives the compressor to compress the produced gas, the compressed gas being directed upwardly through production tubing (20) to surface.

Abstract: The present invention provides an electric submersible pumping assembly that includes an encapsulated pumping device containing a pump, an electric submersible motor, a sealing device at the top, and an opening device at the bottom. The lubricant-filled, initially sealed, encapsulated pumping device allows the pump and motor to be run in the wellbore without contamination and be left intact until operated.

Abstract: A downhole rotary water separation system for the separation and transfer of different density fluids in downhole applications using a pump, a motor, a rotary separator and a shaft-incorporated packer, as necessary, with a minimum of conduits and tubes. Torque can be transferred between all moving components as well as the packer such that the motor and pump can be disposed above or below the separator.

Abstract: A crude oil recovery system includes a downhole pump and an extension that extends below the downhole pump. The extension has an extension inlet positioned below the lowest drawdown level achievable by the pump. All of the fluid pumped by the downhole pump enters the extension via the extension inlet, and by positioning the extension inlet sufficiently below the lowest drawdown level achievable by the pump, pressurized gas is prevented from entering the extension, the pump, or the pump column above the pump. In this way, gas is prevented from displacing oil in the pump column, thereby maintaining excellent cooling for the polish rod, and gas is confined to the borehole annulus, where it can readily be recovered or vented.

Abstract: An apparatus and method for enhancing oil recovery through improved injection well performance is provided, wherein a fluid is injected into the well bore at a pressure P1, and a downhole fluid-actuated engine and pump assembly is employed as a booster in order to generate a high pressure output at pressure Ph greater than P1 and a low pressure output at pressure P1 lower than P1; the respective output streams are directed to lower and higher permeability geological strata adjacent the well bore in order to increase production.

Abstract: A buoyant water pump system for reducing the difficulty involved in removing the pump from a well. The buoyant water pump system includes a conduit having a lumen and a lower end for inserting into the well. A pump assembly for pumping water from the well is mounted on the lower end of the conduit. The pump assembly includes a pump mounted on the conduit adjacent to the lower end thereof, and having an outlet that is fluidly coupled to the lumen of the conduit. A buoyant member is mounted on the conduit adjacent to the pump assembly to keep the pump assembly afloat.

Abstract: A packer is disposed within a wellbore casing. The packer defines a first and a second zone of the wellbore. A submersible pumping system is used to displace liquid from the first zone of the wellbore via a first fluid flow path. A cable is used for supplying power to the submersible pumping system. The cable extends through the tubing that extends from the location. A second fluid flow path extends from the first zone of the wellbore to a surface location. A portion of the second fluid flow path extends through the tubing.

Abstract: A riser is installed which extends from a wellhead near the sea floor to near sea level. An electrical submersible pump assembly is suspended within the riser to pump well fluids up the riser. The electrical submersible pump includes impellers for displacing well fluids, and a base member having an intake port for receiving well fluid. The pump assembly can also include a separator for separating any gases from the well fluids, a packer for sealing the pump to the riser, coiled tubing from the pump to at least the upper end of the riser, or NPSH stages to aid in pumping a mixed flow of well fluids and gas.

Abstract: An integrated pumping system for use in environments, such as subterranean environments, to move a desired fluid from one location to another. The integrated pumping system comprises one or more stages that each have an integrated pump and motor. A controller may be utilized to individually control the one or more integrated pumps and motors.

Abstract: A sample module is provided for use in a downhole tool to obtain fluid from a subsurface formation penetrated by a wellbore. The sample module includes a sample chamber carried by the module for collecting a sample of formation fluid obtained from the formation via the downhole tool, and a validation chamber carried by the module for collecting a substantially smaller sample of formation fluid than the sample chamber. The validation chamber is removable from the sample module at the surface without disturbing the sample chamber. In another aspect, the present invention provides an improved sample chamber for use in a downhole tool to obtain fluid from a subsurface formation penetrated by a wellbore.

Abstract: An electrical submersible pump assembly supported on coiled or continuous tubing. A power cable extends through the coiled tubing for supplying electrical power to the pump assembly. The cable has an outer diameter that is less than the inner diameter of the tubing, resulting in a cable annulus surrounding the cable. Supports attached to the cable frictionally or mechanically engage the cable with the coiled tubing to support the weight of the cable with the tubing. The supports define passages that allow fluid to flow by within the cable annulus from the surface. A port is provided in the coiled tubing at the electrical submersible pump assembly for discharging fluid pumped from the surface down the cable annulus. A tube may be provided to extend downward from the port alongside of the electrical submersible pump. Fluid may be pumped from an upper end of the well down the cable annulus and out of the port to free up sand accumulation on the packer.

Abstract: A system and method for restarting a downhole pump that has seized due to an accumulation of debris above the pump and around the pump intake. The system consists of a flexible annulus sealing element fitted on a joint of production tubing where the annulus seal can be activated by pumping fluid down the well annulus from surface. The tool includes tubing and check valve arrangements such that fluid from the well annulus above the flexible annulus sealing element can enter the production tubing immediately above the downhole pump and circulate debris back to surface as well as introduce fluid to the pump intake to mobilize debris accumulated at the pump intake.

Abstract: An inflatable packer setting tool assembly is lowerable into a subterranean well bore and operable to set an inflatable packer therein. The tool assembly includes a fluid supply housing and a setting tool that is releasably interconnected to an inflatable packer. The setting tool further includes a pump that is fluidly interconnected with the inflatable packer and is operable to inflate the inflatable packer. The fluid supply housing is fluidly interconnected with the setting tool and includes an inflation fluid passageway that has an inlet and outlet which is fluidly interconnected with a suction side of the pump. The inlet is in the form of an aperture on an outer wall of the supply housing and functions to fluidly interconnect the passageway to a source of first inflation fluid present in the well bore when the setting tool assembly is lowered into the well bore.

Abstract: A method and system for the downhole separation and injection of surface water and water contained in a produced mixture from an underground formation of a hydrocarbon well containing hydrocarbon and water. Downhole separation of the produced mixture into a predominately water component and predominately hydrocarbon component is achieved using an oil-water separator. Surface water is delivered to a downhole fluid-driven pump under pressure so as to drive the pump. The downhole-separated predominately water component of the produced mixture is directed to the pump, by way of the pump and combined with surface water to obtain a combined fluid. The combined fluid is directed to a downhole injection formation by way of the pump. Oil is transported to the head of the well either naturally under the eruptive force of the well, or with the assistance of regular artificial lift methods, including gas-lift.

Abstract: A method and system for the downhole separation and injection of a predominately water component of the mixture produced from a naturally flowing or gas-lifted hydrocarbon well. The produced mixture is delivered to a separator located in the wellbore above an injection formation, the separator comprising a gas-liquid separator and an oil-water separator. The produced mixture is admitted to a gas-liquid separator to separate the free gas from the produced mixture. The gas-depleted produced mixture is then admitted to an oil-water separator where the produced mixture is separated into a predominately water component and a predominately hydrocarbon component. The separated gas and the predominately hydrocarbon component are delivered to the surface, separately or commingled. The predominately water is injected in the injection formation accessible through the same wellbore, and located below the separator.

Abstract: A system for separating particulates from a liquid prior to pumping of the liquid. The system is amenable to use, for example, in a wellbore environment for separating sand or other particulate matter from a production fluid. The system uses a sand separator, a submersible pump and a mechanism for reinjecting the particulate matter downstream of the pump discharge. This permits the sand and other particulates to be routed around the pump to reduce the potentially detrimental effects of such particulate matter on certain pumps.

Abstract: A method of performing a downhole well completion cleanup is provided. In a described embodiment, completion fluids from a first zone are flowed into a tubular string, and then the fluids are discharged into a second zone. An apparatus usable in the method is provided, in which a downhole pump is utilized to pump the fluids from one zone to the other. The pump may be operated in a variety of manners. The apparatus may also include fluid identification sensors and telemetry devices for monitoring the progress of the cleanup operation.

Abstract: A method for installing a submersible pump assembly that allows deployment in a live well under pressure. In some of the embodiments, a pressure barrier is installed in the well lower than a length of the submersible pump assembly. The submersible pump assembly is lowered on a line into the chamber, then a lubricator at the surface seals around the line by allowing the pressure barrier to be released and the submersible pump assembly to be lowered into the well to a desired depth. Preferably, there is a lower pressure barrier in the well. The upper pressure barrier may be a packer that may be collapsed and retrieved alongside the submersible pump assembly. The pressure barrier also may be a packer that is temporarily set in the well, then engaged by the submersible pump assembly, with the pump assembly and packer then being lowered as a unit to a further depth in the well.

Abstract: A dual submergible pumping system permits the production and/or injection of fluids from or into separate zones within a narrowly confined wellbore without commingling of fluids. The system includes at least first and second electric submergible pumping systems. Typically, the design allows the electric submergible pumping systems to be arranged generally axially within a wellbore. Each system, however, is able to produce or inject fluids along a fluid flow path that is isolated from the fluid flow path of the other electric submergible pumping system.

Abstract: A downhole injector 10, 26, 38 and 54 is provided at the lower end of the production tubing string TS for passing liquids from a downhole formation into the tubing string while preventing gases from passing through the injector. The injector may include an improved screen 36 for preventing formation sand from entering the injector. The system may include a packer 44 in the annulus A above the injector. In one application, a vent tube 46 extends upward from the packer into the annulus for maintaining a desired liquid level in the annulus above the packer. A plurality of through ports 40 establish fluid communication in the annulus above the packer and the production tubing string so that a downhole pump P may efficiently pump downhole fluids to the surface. The injector of the present invention may be used with one or more lift valves LV for raising slugs of liquid upward to the surface through the production tubing string.

Abstract: A device insertable into a cased well consisting of an elastic tube, a pipe having an inner bore, the pipe extending through the elastic tube, the elastic tube annularly surrounding an expansion space; tube clamps capable of fixedly attaching the upper and lower ends of the elastic tube to the outer surface of the pipe; and fluid transfer apertures capable of carrying fluids from the inner bore of the pipe to the expansion space, the fluid transfer apertures interconnecting the expansion space and the inner bore of the pipe so that, upon extension of the device into the cased well, and upon introduction of a pressurized water into the inner bore of the pipe, the water may flow from the inner bore of the pipe into the expansion space, causing the outer surface of the elastic tube to expand radially outward into is contact with the well's casing.

Abstract: An oil well system for extracting oil extracted from a reservoir via a well, INCLUDES a separator device adapted to separate oil and water from a mixture extracted from a reservoir. The separator device has a non-vertical first flow path for the mixture and being arranged along a non-vertical portion of the well, a second flow path, separate from the first flow path, for receiving water or a water enriched phase that has been separated from the mixture by the separator device, and a plurality of drain openings along a section of the first flow path. The first and second flow paths are arranged such that water or the water enriched phase in the first flow path can flow by gravity to the second flow path via the drain openings. An opening area of the drain openings, per unit area of the first flow path, decreases in a flow direction of the mixture along the first flow path.

Abstract: The pumping sub comprises first and second inflatable bladders which are pressurized to inflate to accommodate various pipe diameters. Pressure relief value means is provided to assist in clearing obstructions within the pipe. The pumping sub acts as a parachute to slow the fall of a logging tool and enables the logging tool to be pumped up and down a drill pipe. FIG.

Abstract: The invention concerns a pumping installation designed for being mounted in an oil well extending from the surface to a layer of oil-bearing rock, comprising a pipe column at the lower end of which is mounted a pump, a joint, mounted in the well around the pipe column and delimiting a chamber at the lower end of the well, in which is arranged a pump. The installation further comprises a hydro-ejector, in the pipe column, including a lower pressure zone opening into the upper end of the chamber.

Abstract: A downhole injector 10, 26, 38 and 54 is provided at the lower end of the production tubing string TS for passing liquids from a downhole formation into the tubing string while preventing gases from passing through the injector. The injector may include an improved screen 36 for preventing formation sand from entering the injector. The system may include a packer 44 in the annulus A above the injector. In one application, a vent tube 46 extends upward from the packer into the annulus for maintaining a desired liquid level in the annulus above the packer. A plurality of through ports 40 establish fluid communication in the annulus above the packer and the production tubing string so that a downhole pump P may efficiently pump downhole fluids to the surface. The injector of the present invention may be used with one or more lift valves LV for raising slugs of liquid upward to the surface through the production tubing string.

Abstract: A safety valve and pump apparatus has an electric pump, a safety valve, a packing means, a continuous length of tubing extending from the surface to the location of the safety valve and pump, a control means provided to operate the safety valve and the pump, and a transmission means disposed along the tubing to transmit signals from the control means to the safety valve and the pump. The tubing, the safety valve and the pump are all being concentrically aligned The electric pump is releasably attached to the safety valve by pump connection means, so that the pump may be disconnected from the apparatus above and left in the well, and may afterwards be retrieved. Likewise, the safety valve is releasably attached to the packing means by packer connection means.

Abstract: A connector permits separation of a submergible pumping system from its deployment system. The connector includes an upper assembly and a lower assembly that are connected by shear screws. A hydraulic separation mechanism is used to shear the shear screws and separate the upper and lower assemblies from a remote location.

Abstract: A pumping assembly for use on an offshore drilling platform. The pumping assembly includes a vertical pump designed for mounting on the deck of an offshore drilling platform. The pump is a vertical pump that includes a fluid intake, a fluid discharge, a rotatable shaft, and a fluid driving mechanism to draw fluid into the fluid intake and to discharge fluid through the fluid discharge. A seal is mounted about the rotatable shaft to prevent leaking of the pumped fluid along the rotatable shaft. Additionally, a power source is coupled to the rotatable shaft to power the vertical pump. The fluid discharge is oriented to discharge fluid in a direction generally axially aligned with the rotatable axis to limit transverse forces on the seal.

Abstract: A system for separating fluids of differing densities includes a pair of pumps interconnected to and driven by a motor positioned therebetween. The pumps each have intake ends, distal second ends, and a pump intake proximal the intake end. The pumps, the motor, and a production tubing form a production string. A shroud is sealably connected to the production string at one end of the shroud at a position intermediate the motor and the pump intake of one of the pumps. The shroud surrounds the pump and extends at least partially over the pump. The shroud forms a fluid communication passageway between the pump and the shroud and an orifice at the end of the shroud opposite the sealed end to form an effective pump intake. A second shroud similar to the first shroud surrounds the other, second pump and is sealably attached to the production string intermediate the motor and the second pump. The effective pump intakes formed by the shrouds are at least sixty feet from one another.

Abstract: A system of reciprocating bottom hole sucker rod pumps, situated in an oil well, to produce an oil rich stream to surface and inject a water stream to a same wellbore disposal zone. Two pumps vertically in tandem are actuated by a single sucker rod string. Separate intakes for each pump are situated so as to allow for gravity to segregate oil and water in the wellbore before reaching the intakes. Both streams are produced out of the pumps on the upstroke. Injection of the water stream is facilitated by an outer housing around the bottom pump to redirect flow to a disposal zone.

Abstract: An artificial lift, concentric tubing production system for a well and method of using same. The system including an upper concentric tubing string portion comprising an inner production tubing string positioned within an outer production tubing string. A flow crossover assembly is connected to the upper concentric tubing string portion. The flow crossover assembly has first and second passageways. The inner production tubing string is in fluid communication with the first passageway and the outer production tubing string in fluid communication with the second passageway. An upper transducer is in fluid communication with one of the passageways of the flow crossover assembly and a lower apparatus is in fluid communication with the other of the passageways of the flow crossover assembly. The upper transducer may be a pump such as an electric submersible pump or a progressive cavity pump. The lower apparatus may be a pump, including an electric submersible pump, or a liquid/gas separator.

Abstract: An assembly for use in a well containing a mixture of hydrocarbons and water wherein the assembly separates hydrocarbons or relatively lighter fluids from the mixture and injects water or relatively heavier fluids into the well. The assembly includes an upper pump that pumps the relatively lighter fluids to the surface. A tandem pump is positioned below the upper pump for pumping well fluids down to a downhole separator. An oil bypass tube is provided in communication with the tandem pump for transferring the relatively lighter fluids to the upper pump, for subsequent pumping to the surface. A recycle tube is also provided that communicates with the downhole separator and the tandem pump for transferring at least a portion of the relatively heavier fluids from the downhole separator to the tandem pump, for pumping the relatively heavier fluids back to the separator.

Abstract: A separation system for protecting a pump disposed in a well. The separation system separates sand from the well fluid prior to pumping of the well fluid. The separated sand, or other particulates is routed past the pump used in producing the desired well fluid. The sand is then reinjected into the produced fluid stream at a location downstream of the pump.

Abstract: An improved electrical submersible pump is disclosed in which a processor downhole is utilized to monitor one or more subsurface conditions, to record data, and to alter at least one operating condition of the electrical submersible pump. Novel uses are described for downhole gas compression, the delivery of particulate matter to wellbore sites, and for the disposal of waste.

Abstract: A controlled release method for a submergible completion is disclosed wherein upper and lower interface assemblies are separated from one another in a predictable manner. A separation or release assembly is actuated remotely for forcing the interface assemblies apart. The release assembly may shear pins extending between portions of the interface assemblies. The interface assemblies may include multi-conductor electrical plugs or connectors which are separated during release.

Abstract: Methods and apparatus are provided for separation of liquids of different densities in production fluid streams from underground wells. Methods and apparatus are also provided for separation of gas, oil and water in production fluids, transportation of the separated fluids to the surface, as well as reinjection of separated water from the production fluids into other formations. Other aspects include new separation arrangements which include gas or liquid driven motors, designs for multi-stage hydrocyclone separators and use of beam or rod pumps.

Abstract: The present invention relates to an apparatus and method for selectively lifting produced fluids, including produced hydrocarbons and a portion of produced water, to a ground surface while injecting the remaining produced water into an injection zone subsurface in a subterranean well. The invention preferably utilizes an electrical submersible progressive cavity pump (ESPCP) in conjunction with an electrical submersible pump (ESP) in order to carry out the dual injection and lifting steps. Further, this apparatus and method make it possible to produce hydrocarbons from oil wells in a manner that poses less risk and disturbance to the environment.

Abstract: A downhole tool is described which can be used for injection of waste fluids which have been separated from desired production fluids into a disposal formation. When desired, the conduit for the waste fluids to the disposal formation can be closed off, thereby isolating the disposal formation from the production zone and providing access selectively to the production zone.

Abstract: The present invention relates to a downhole oil and water separation system having a casing which includes an interval in communication with a producing zone. The system further includes two pumps disposed in the casing for use in lifting segregated produced hydrocarbons and portion of produced water and segregated produced water to the ground surface.

Abstract: The present invention relates to an apparatus and method for selectively lifting produced fluids, including produced hydrocarbons and a portion of produced water, to a ground surface while injecting the remaining produced water into an injection zone subsurface in a subterranean well. The invention preferably utilizes a rod-driven progressive cavity pump (RD-PCP) in conjunction with an electrical submersible pump (ESP) in order to carry out the dual injection and lifting steps. Further, this apparatus and method make it possible to produce hydrocarbons from oil wells in a manner that poses less risk and disturbance to the environment.

Abstract: A downhole injector 10, 26, 38 and 54 is provided at the lower end of the production tubing string TS for passing liquids from a downhole formation into the tubing string while preventing gases from passing through the injector. The injector may include an improved screen 36 for preventing formation sand from entering the injector. The system may include a packer 44 in the annulus A above the injector. In one application, a vent tube 46 extends upward from the packer into the annulus for maintaining a desired liquid level in the annulus above the packer. A plurality of through ports 40 establish fluid communication in the annulus above the packer and the production tubing string so that a downhole pump P may efficiently pump downhole fluids to the surface. The injector of the present invention may be used with one or more lift valves LV for raising slugs of liquid upward to the surface through the production tubing string.

Abstract: A downhole tool is described can be used for handling waste fluids separated from desired hydrocarbon production fluids. The waste fluids are injected into a disposal formation. The tool is produced to avoid blockage of fluid flow passages and to reduce or eliminate the creation of a pressure differential across the tool. The tool is adaptable to be used with various sizes of pumps, to accommodate various pump intake filters and to conform to API tolerances. The downhole tool includes: an inner tube having a longitudinal bore, a seal disposed at the lower end of the longitudinal bore, an outer tube having an outer surface and being disposed about and spaced from the inner tube. An annulus is formed between the inner tube and the outer tube and is open at each end. A threaded connection is formed at the upper end of the outer tube to connect the outer tube to a tubing string such that the annulus opens into the tubing string's longitudinal bore.