Abstract: A fluid level control mechanism comprising a float assembly, a flow line assembly, an upper centralizer, and a lower centralizer. The float assembly has a cylindrical outer float tube and a cylindrical inner float tube connected by upper and lower end plates to form a sealed cavity. The flow line assembly has a main flow line capable of passing a fluid, a diverter flow line, and a diverter valve. The diverter valve is connected to the lower end plate of the float assembly via a lever arm, such that the float assembly is capable of sliding along the length of the main flow line in response to a fluid level. Downward movement of the float assembly opens the diverter valve and upward movement of the float assembly closes the diverter valve. The upper and lower centralizers center the mechanism within a well bore.

Abstract: A pumping system includes a hydraulic motor assembly configured to drive a production pump. The hydraulic motor assembly includes a master pump located on the surface and an electric motor configured to controllably power the master pump. When moved by the electric motor, the master pump discharges a working fluid under pressure. The pressurized working fluid is transferred to a hydraulic turbine located in the wellbore. The hydraulic turbine converts the pressure of the working fluid into torque, which is transferred through a driveline to a production pump. The production pump pressurizes production fluids, which are carried under pressure to the surface.

Abstract: Detecting a failure mode of a fluid flow controller configured to control fluid flow between first and second chambers of a downhole positive displacement pump and a flow line, wherein the positive displacement pump comprises a piston moving in an axial reciprocating motion, and subsequently adjusting operation of the downhole positive displacement pump based on the detected failure mode such that the downhole positive displacement pump piston operates differently in different axial directions.

Abstract: Vibration of an electric submersible pump assembly is monitored to produce a vibration spectrum. The vibration spectrum is compared to a known vibration signature for a pump condition that precedes gas lock. The pump condition is at least one of an impeller rotating stall condition, a diffuser stall condition, a pre-surge condition, and percentage of free gas within the wellbore fluid. Operation of the pump is then adjusted in response to the similarity of the vibration spectrum to the vibration signature for the pump condition to prevent impending gas lock.

Abstract: A wellbore servicing system disposed at a wellbore, the wellbore servicing system comprising at least one wellbore servicing equipment component, wherein a flow path extends from the wellbore servicing system component into the wellbore, and a flow-back control system, wherein the flow-back control system is disposed along the flow path, and wherein the flow-back control system is configured to allow fluid communication via the flow path in a first direction at not less than a first rate and to allow fluid communication via the flow path in a second direction at not more than a second rate, wherein the first rate is greater than the second rate.

Abstract: A tandem progressive cavity pump system lifts well fluids from a production zone to a well surface. The system provides a first pump and a second pump. The system positions the first pump at the production elevation within the well, and the second pump at an intermediate elevation within the well. The system then connects a discharge of the first pump to an intake of the second pump. The system is then operated so that the first pump lifts well fluids from the production zone to the intermediate zone, depositing the well fluids in the intake of the second pump. The second pump then lifts the well fluids from the intermediate zone to the surface of the well.

Abstract: A downhole tool includes a pump to facilitate a flow of sampling fluid through the downhole tool. The sampling fluid flows from an inlet of the downhole tool toward an outlet of the downhole tool or to a sampling chamber. The downhole tool also includes a sensor located in the pump. The sensor facilitates a calculation of a pumping efficiency of the downhole tool.

Abstract: A down-hole jet pumping apparatus and method for removing accumulated water in a small diameter well bore are described. Chosen fluids are pumped under high pressure from a surface pump through a 3-way valve into a tube disposed in a well bore. The jet pumping apparatus includes a down-hole accumulator connected to an eductor. The high-pressure fluid is stored in the accumulator and may be released to the surface reservoir by the control valve through the tube along with the fluid to be pumped drawn into the eductor. When the accumulator is exhausted, the control valve again directs high-pressure fluid from the surface pump to the accumulator until a chosen pressure is achieved in the accumulator. The fluid pressure in the accumulator is maintained using a gas-charged metal bellows. Hydraulically driven jet boosters are described for increasing the fluid pressure along the tube in deep wells.

Abstract: A pump comprising: a pump barrel for use within a well; a reciprocating plunger disposed within the pump barrel and operatively engaging a removable connector adapted to flushly secure over the top of the plunger; said connector operatively engaging a pumping unit; the connector further comprising: an inner and outer portion with an upwardly disposed tapered edge between the inner and outer portions; and one or more tubular ports extending generally diagonally from the axis of the connector and adapted to expel fluids through hydraulic pressure resulting from the reciprocating action of the plunger and wherein said ports are annularly disposed between the upwardly disposed tapered edge and the inner portion and accessing an inner cavity of the connector; the connector further comprising an axial bore adapted to allow fluids to pass through the connector and further comprising one or more upper fluid bypass ports disposed on the inner portion.

Abstract: A pumping system includes a probe to suction a fluid from a fluid reservoir, a pump in fluid communication with the probe, and a sensor for detecting phase changes in said pumping system. The sensor is in fluid communication with the probe or pump and is operable to generate a sensor signal. The pumping system also includes a fluid exit from the pumping system that is in fluid communication with said pump, and a variable force check valve that is located between the probe and fluid exit.

Abstract: A lubricator is provided which has a unitized body with at least one port in communication with the body's bore and its outer surface, to which port(s) connectors with different outer fittings for further connection to other equipment may be attached and sealed, and later detached and replaced with other connectors. The connectors may have different outer fittings or may be a plug or valve. This allows the connection of a single port to external equipment to be changed and the fitting for that external equipment's connection to be altered, without having to disconnect the lubricator from its well-head and stem or any of the lubricator's other connections.

Abstract: A system for attaining and maintaining a pre-determined fluid level in a petroleum-producing well having a pump, such as a progressive-cavity pump, and a pump motor having a variable-frequency drive control using two sensors: a pump pressure sensor located at the pump depth and a casing pressure sensor located at the casinghead of the well. A programmable computer is connected to the first and second pressure sensors and the motor speed control so that the programmable computer controls the operation of the pump motor to attain and maintain a target fluid level in the well over a predetermined time interval for reaching the target fluid level in the well. The programmable computer computes an error signal to control a variable frequency drive motor, where the error signal is computed periodically from the difference between in the actual fluid level in the well and the target fluid level in the well according to a rate reference curve.

Abstract: A pumping arrangement employs a compensating type hydraulic pump, a directional valving arrangement and a proportioning valving arrangement. When the directional valve is energized, oil is directed to the rod end of the hydraulic cylinder. The rod or piston part of the hydraulic cylinder will then elevate until a first limit switch is actuated which then will de-energize the directional valve and send a current signal to the proportional valve. This current signal to the proportional valve forces it to open to a point at which the cylinder rod would extend at the desired velocity until it reaches a second limit switch. The current signal to the proportional valve is then decreased, creating a choking arrangement that forces the cylinder rod to decelerate. Upon reaching the third limit switch, the signal is removed from the proportional valve so that it closes.

Abstract: A valve with a shuttle for use in a flow management system is capable of bypassing a backflow.

Abstract: A slim hole production system for pumping liquids to the surface of a hydrocarbon well and especially a hydrocarbon well that is producing both natural gas and liquids where the diameter of the hole in the production area is too small to get production tubing and a sucker rod into a productive arrangement. The slim hole pump includes a hollow tube that raises and lowers the plunger and carries the liquids to the surface and uses the annulus to produce the gas.

Abstract: A section of riser casing urges drilling mud through the riser, either upward from the sea floor to reduce head pressure or downward toward the wellbore. The section of riser casing may use an electromagnet, two or more electrodes, or a combination of electromagnets and electrodes to urge drilling mud having electrohydrodynamic properties through the riser casing.

Abstract: A plunger for removing fluid from a gas producing well has a fluid path through the plunger body, a narrow passageway within the fluid path, and a central orifice at an end of the passageway. The plunger may have a lip within the fluid path spaced above the central orifice. The lip can interact with gas and fluid exiting the central orifice when the plunger is rising within the gas producing well. The lip may be provided by an internal fishing neck. The plunger may have a bypass valve to allow the plunger to fall while the well is flowing, and may have a central constriction to regulate the rate of falling.

Abstract: A method to produce formation fluid from an oil or gas well. The methods employs a jet pump and a spoolable multi-string tubing system. The jet pump is adapted to produce formation fluid, which may be produced in combination with power fluid. The multi-string tubing system consists of two or more tubing conduits, allowing surface pump equipment to deliver power fluid to the jet pump down a supply tubing string, while return fluid is returned up a return tubing string. Other downhole functions can be provided with the inclusion of additional features on the jet pump and additional conduits or conductors in the multi-string tubing system. Preferred embodiments provide additional functionality by inclusion of a jetting sub, sensing elements, or a back-pressure valve to the jet pump, and auxiliary tubing strings or communication members to the spoolable multi-string tubing system.

Abstract: A submersible pumping system for use downhole, wherein the system includes a pump, a pump motor, a seal section, a shaft coupling the pump motor to the pump, and bearing assemblies for radially retaining the shaft in place that are offset with respect to an axis of the shaft. The offset bearing assemblies produce side loads in the shaft that reduce shaft vibration during use. The bearing assemblies can be a combination of symmetric and asymmetric assemblies set in an alternating pattern along the length of the shaft.

Abstract: A pump includes one or more stages, each stage including a tubular housing and a mandrel disposed in the housing. The mandrel includes a rotor rotatable relative to the housing and having: an impeller, a shaft, and one or more helicoidal blades on an outer surface of the impeller. The mandrel further includes a diffuser: connected to the housing, having the rotor shaft extending therethrough and having a plurality of vanes on an outer surface thereof. Each vane has an arcuate portion and a longitudinal portion. The diffuser further has a channel formed between an adjacent pair of vanes. The pump further includes a fluid passage formed between the housing and the mandrel.

Abstract: A method and apparatus for reducing erosion and friction losses in a wellbore using a power cabled deployed electric submersible pump (ESP). The apparatus can include an ESP disposed within production tubing, wherein a portion of the production tubing surrounding the ESP contains fluid openings that are operable to allow produced fluids to flow outward, thereby increasing the available volume for the produced fluids. The increased volume results in lower fluid velocities of the produced fluid, which advantageously reduces erosion and friction loss.

Abstract: A method facilitates transmission of electric signals across well components which move relative to each other in a wellbore environment. The method utilizes well components which are movably, e.g. rotatably, coupled to each other via one or more conductive bearings. Each conductive bearing has a conductive rolling element which enables relative movement, e.g. rotation, between the well components while simultaneously facilitating transmission of electric signals through the bearing. The method also involves coupling portions of the bearing to each of the well components, and those bearing portions may be connected with electric leads to enable flow of electric signals through the bearing during operation of the system downhole.

Abstract: A method for lifting fluids within a subterranean well includes lowering an elongated plunger to a lower region of a bore of the subterranean well. The plunger includes a motor assembly operably connected to a propeller. A seal can be created between the plunger and an inner surface of the bore of the subterranean well. A thruster, such as motor assembly connected to a propeller, generates thrust to lift the plunger to a plunger retainer located proximate to a wellhead of the subterranean well.

Abstract: A reciprocating apparatus for pumping pressurized fluid. The reciprocating apparatus comprises a plunger disposed within a cylinder, wherein the plunger is hollow and ported for enabling fluid within the cylinder to flow into the plunger. The plunger includes at least one outlet through which fluid within the plunger flows out of the plunger. In operation, the plunger retracts to displace fluid from the hollow body and into a discharge chamber, and the plunger extends towards the discharge chamber to discharge the displaced fluid. As the plunger alternately retracts and extends, fluid within the plunger continuously flows towards the discharge chamber.

Abstract: A deliquification pump for deliquifying a well comprises a fluid end pump adapted to pump a fluid from a wellbore. In addition, the deliquification pump comprises a hydraulic pump adapted to drive the fluid end pump. The hydraulic pump includes a first internal pump chamber and a first pump assembly disposed in the first chamber. The first pump assembly includes a piston having a first end, a second end, and a throughbore extending between the first end and the second end. In addition, the first pump assembly includes a first wobble plate including a planar end face axially adjacent the second end of the piston and a slot extending axially through the first wobble plate. The first wobble plate is adapted to rotate about the central axis relative to the housing to axially reciprocate the piston and cyclically place the throughbore of the piston in fluid communication with the slot.

Abstract: A deliquification pump for deliquifying a well comprises a fluid end pump adapted to pump a fluid from a wellbore. In addition, the deliquification pump comprises a hydraulic pump adapted to drive the fluid end pump. The hydraulic pump includes a first internal pump chamber and a first pump assembly disposed in the first chamber. The first pump assembly includes a piston having a first end, a second end, and a throughbore extending between the first end and the second end. In addition, the first pump assembly includes a first wobble plate including a planar end face axially adjacent the second end of the piston and a slot extending axially through the first wobble plate. The first wobble plate is adapted to rotate about the central axis relative to the housing to axially reciprocate the piston and cyclically place the throughbore of the piston in fluid communication with the slot.

Abstract: A submersible pump system that is operable to permit selective access into a production zone of a well bore while a submersible pumping device is operating includes a Y-tool, a submersible pumping device, a control valve assembly and a power conduit. The control valve assembly is also operable to selectively permit access between the interior of the submersible pumping system and the exterior of the submersible pumping system. The valve is operable to form a dynamic seal. The power conduit is operable to convey both power and a pre-designated control signal simultaneously. A method for accessing the production zone of the well bore with a well bore tool uses the submersible pump system while the submersible pump system is producing production zone fluid. The submersible pumping device continues to operate without interruption after transmission of the pre-designated pump control signal.

Abstract: A system and method are provided for improving hydrocarbon production from gaseous wells, and in particular improving hydrocarbon production using pumping systems employing artificial lifts. The pumping system of the well is controlled so as to cyclically decrease and increase gas pressure in the casing annulus, thus cyclically decreasing PBHP in response to the decrease in the casing annulus pressure and permitting the PBHP to increase in response to the increase in casing annulus pressure. Production of fluid from the reservoir is therefore increased during the cyclical decrease in casing annulus pressure, and production of fluid from the downhole pump is increased during the cyclical increase in casing annulus pressure. In addition, gas interference due to production of foam in the casing surrounding a downhole pump can be mitigated by forcing liquid from the foam during the period of increased casing annulus pressure.

Abstract: A crude oil production equipment includes a submersible pump coupled with a driving shaft, a linear motor, an oil pipe, a well casing, a filter pipe, an outer passage, an inner tube, an upper valve ball, a piston and a lower valve ball. During down stroke of the driving shaft, a suction force is produced to suck crude oil from the well casing into the upper chamber of the inner and the piston forces crude oil out of the lower chamber of the inner tube into the inner passage and then the outlet of the oil pipe. During up stroke of the driving shaft, the piston forces crude oil out of the upper chamber into the lower chamber, and the driving shaft enters the upper chamber and the lower chamber to force crude oil out of the lower chamber out of the oil outlet of the oil pipe.

Abstract: A brake actuator has a motor that provides input rotation in first and second directions. A reducer couples to the motor and reduces the input rotation into an output rotation to be applied to a brake screw of a progressive cavity pump drive. A sensor measures rotational speed of the drive shaft. In manual operation, an operator can view an indication of the rotational speed and can manually operate the motor accordingly to control rotation of the shaft. In automated operation, a controller automatically controls the motor based on the rotational speed measured by the sensor. The controller can also use a torque sensor to detect the torque applied to the brake screw, a displacement sensor to detect displacement of the brake screw, and/or a current sensor to detect the current consumption of the motor.

Abstract: A plunger for removing fluid from a gas producing well has a fluid path through the plunger body, a narrow passageway within the fluid path, and a central orifice at an end of the passageway. The plunger may have a lip within the fluid path spaced above the central orifice. The lip can interact with gas and fluid exiting the central orifice when the plunger is rising within the gas producing well. The lip may be provided by an internal fishing neck. The plunger may have a bypass valve to allow the plunger to fall while the well is flowing, and may have a central constriction to regulate the rate of falling.

Abstract: A downhole pumping system includes a motor, a pump driven by the motor and a seal section positioned between the pump and the motor. The seal section preferably includes a first seal bag assembly, a second seal bag assembly and an interconnect module connected between the first seal bag assembly and the second seal bag assembly. The interconnect module includes a plenum, at least one fluid exchange passage connected to the plenum, and a shaft seal assembly. The shaft seal assembly is configured to divert fluid from the plenum into the at least one fluid exchange passage. In another aspect, a first group of interconnect modules within the seal section each includes a shaft seal assembly oriented in a first direction and a second group of the interconnect modules each includes a shaft seal assembly oriented in a second direction to selectively apply an axial force on the shaft.

Abstract: The present invention relates to a submersible pump and a submersible pump system for pumping liquid to a marine structure, the pump being adapted to be located in a tube. The pump comprises an upper portion and a lower portion. The upper portion is adapted to be connected to means for suspending the pump in the tube. The pump has a vertical direction extending from the lower portion to the upper portion. The pump further comprises an inlet for allowing the liquid into the pump and an outlet for allowing the liquid out of the pump. The pump further comprises a sealing means located downstream of the inlet and the outlet in the vertical direction, the sealing means being adapted to seal against an inner surface of the tube. The invention further relates to an arrangement for hydraulic drive of the submersible pump and to a semi-submersible unit comprising the submersible pump system.

Abstract: A downhole pump is operated by a non-electric motor preferably a steam turbine. In a steam assisted gravity drain system the producing well is U-shaped. A steam supply line runs into the turbine that drives the pump after the steam supply passes through a packer. The steam exhaust runs through a shroud until the U-shaped well turns back to go up to the surface. Pump suction is thus separated from steam discharge to reduce mixing as the path of least resistance for the discharged steam when it exits the shroud is up to the surface. The exhaust steam keeps the produced fluids warm and flowing. An injector well runs parallel and slightly above the horizontal portion of the U-shaped producing well.

Abstract: Certain aspects and embodiments of the present invention are directed to a dual closure system disposed within a wellbore and capable of preventing the production of fluids from a fluid-producing formation to the surface. The dual closure system can include a passive closure mechanism and a subsurface safety valve coupled to an electric submersible pump positioned within a passageway defined by the tubing string. The passive closure mechanism and the subsurface safety valve can prevent production of fluid in the absence of the subsurface safety valve. The subsurface safety valve can be positioned within a passageway defined by a tubing string such that the subsurface safety valve can apply force to the passive closure mechanism. The force applied to the passive closure mechanism can maintain the passive closure mechanism in an open position, allowing movement of fluid to the surface in the presence of the active closure mechanism.

Abstract: A filter sub apparatus comprising a housing configured to contain a filter and a bypass mechanism is provided. The bypass mechanism may be actuated upon debris buildup on the filter resulting in a load applied to the bypass mechanism rising above a predetermined lower level. A method to prevent chemical injection process failures may also be provided. The method may comprise the steps of providing a filter sub prior to a check valve. The filter sub may include a filter and a bypass mechanism. Another step may be passing fluid through the filter. In addition, the steps may also include containing at least some debris on a side of the filter such that the debris is prevented from reaching the check valve. A further step may be actuating the bypass mechanism after the debris builds up to a level in which a resulting load applied to the bypass mechanism exceeds a lower limit.

Abstract: An oil well pumping apparatus for pumping oil from a well to a wellhead provides a tool body that is sized and shaped to be lowered into the production tubing string of the oil well. A working fluid is provided that can be pumped into the production tubing. A flow channel into the well bore enables the working fluid to be circulated from the prime mover via the production tubing to the tool body at a location in the well and then back to the wellhead area. A pumping mechanism is provided on the tool body, the pumping mechanism includes upper and lower impeller devices. The upper impeller device is driven by the working fluid. The lower impeller device is rotated by the upper impeller device. Each upper and lower impeller devices are connected with a shaft. A specially configured flow diverter directs the working fluid to an impeller blade in between the top and bottom of an upper impeller device.

Abstract: Certain aspects and embodiments of the present invention are directed to a subsurface safety valve that can be disposed in a wellbore that is through a fluid-producing formation. The subsurface safety valve can include a closure mechanism, a sleeve, and a control line. The closure mechanism can be positioned in a passageway defined by a tubing string. The closure mechanism can be configured to prevent a flow of fluid to a portion of the passageway that is closer to a surface of the wellbore than the closure mechanism. The sleeve can be positioned in the passageway adjacent to the closure mechanism. The control line can communicate pressure to a piston from a pressure source within an inner diameter of the tubing string, causing the piston to apply a force to the sleeve. The sleeve can open the closure mechanism in response to the force being applied to the sleeve.

Abstract: A string for drilling a well for installation and retrieval of ESP equipment without a rig. A well is drilled past the end of casing which has been cemented in place and extends to a wellhead at the surface. A receptacle is attached between production casing joints and run into the well 10. The receptacle is a tubular member with an inclined pocket formed on a side. At least one passage or port in the pocket intersects with a passage in receptacle with one or more lengths of tubing attached to the pocket. A wet connector within the production casing is landed in the receptacle and self aligns to the tubing. Electrical wires run within the tubing mate and lock with the wet connector. This allows an ESP to be run into the well via winch such that it stabs into the wet connector to receive power.

Abstract: Embodiments of the present invention generally relate to a method and/or apparatus for deploying wireline tools with a non-electric string. In one embodiment, a method of determining a free point of a tubular string stuck in a wellbore includes deploying a tool string in the stuck tubular with a non-electric string. The free point assembly includes a battery, a controller, and a free point tool. The method further includes activating the free point tool by the controller. The free point tool contacts an inner surface of the stuck tubular string. The method further includes applying a tensile force and/or torque to the stuck tubular string; and measuring a response of the tubular string with the free point tool.

Abstract: A plunger for removing fluid from a gas producing well has a fluid path through the plunger body, a narrow passageway within the fluid path, and a central orifice at an end of the passageway. The plunger may have a lip within the fluid path spaced above the central orifice. The lip interacts with gas and fluid exiting the central orifice when the plunger is rising within the gas producing well. The plunger may have a bypass valve to allow the plunger to fall while the well is flowing, and may have a central constriction to regulate the rate of falling.

Abstract: An apparatus for a plunger lift mechanism with a main channel disposed between a first and second valve. The first valve is closed by engaging a sealing member to a first seat at a proximal end of the main channel and the second valve consequently closes to with a sealing member engaging a second seat at a distal end of the main channel. An amount of pressure accumulates on a first side of the plunger lift to overcome a pressure on a second side of the plunger lift to force the plunger lift to traverse a well bore and evacuate any fluids present above the plunger lift.

Abstract: A latching mechanism for selectively disengaging an upper pump from a motor in an ESP. The latching mechanism comprises barbs formed on an upper end of an upper shaft that are engaged by a tool to lift the upper shaft until a lower end of the upper shaft disengages from an upper end of a motor shaft. When the upper pump is disengaged from the motor shaft, only a lower pump is driven by the motor and flow of well fluid is circulated past the disengaged upper pump via a bypass line. The upper pump shaft may reengage the motor shaft if additional lift is required.

Abstract: A progressing cavity pump assembly utilizes a reinforced upper section of the stator rubber helix. The pump stator is located at the end of a string of tubing. The reinforced upper section of the stator rubber helix is strong enough, whether reinforced by mechanical means or by strengthening the rubber matrix chemically, so as not to allow the passage of a stop located above or on the top of the pump rotor. The rotor is lowered on a string of rods until the stop above or on top of the rotor lands onto the reinforced upper section of the stator rubber helix. The rotor is then repositioned away from the stator helix a predetermined distance before pump operation begins with rod string rotation.

Abstract: A method and a system are provided for a direct drive pump for use in pumping fluids and/or quasi-fluids from one location to another. In the direct drive pump, bearings or bushings are optimally spaced, taking into account various operational considerations such as load, path, pressure, and tension. Further, bearings or bushings are coupled to the drive string, thus assisting in more efficient installation and de-installation. The bearings or bushings are not fixed to the production casing or drive tube. In embodiments, the drive tube can be vented, and the production fluid can be used as a lubricant for the system bearings.

Abstract: A method of treatment of water in an aquatic environment. Water is first pumped from a reservoir to a first mixing station. An inert gas is introduced into the pumped water at the first mixing station to provide inert gas saturated water, which inert gas saturated water will displace undesired gasses in the water in the reservoir. The inert gas saturated water is then pumped to a sparging column such that the inert gas and undesired gasses will be released from the inert gas saturated water to provide depleted water.

Abstract: The invention is generally directed to the novel and unique water pump system that is for manual operation, such as when there is a power failure and electrical pump systems are inoperable. When air is delivered into the air input port of the air line conduit, the air pushes water residing in the static chamber and water conduit up through the main water line and into an optional expansion tank for use. An electrical air compressor may be used to deliver the air. The water pump system may be provided in a parallel configuration for continuous operation and also in a stacked series configuration for deep well environments.

Abstract: A method of unloading liquid from a reservoir includes deploying a pumping system into a wellbore to a location proximate the reservoir using a cable. The pumping system includes a multi-section motor, an isolation device, and a pump. The method further includes supplying a power signal from the surface to the motor via the cable and sequentially operating each section of the motor to mimic a multi-phase motor, thereby driving the pump and lowering a liquid level in the tubular string to a level proximate the reservoir.

Abstract: A completion system, including a barrier valve transitionable between an open position and a closed position. An upper completion is operatively coupled with the barrier valve for mechanically transitioning the barrier valve to the closed position when the upper completion is withdrawn. A method of operating a completion system is also included.

Abstract: The present invention relates to a downhole sampling tool for taking out fluid samples of a fluid present in a casing having an internal cross-sectional casing area. The downhole sampling tool comprises a first tool part and a second tool part, a sampling inlet arranged in the first part, and an actuation unit arranged in the second part adapted to move the sampling inlet into contact with the fluid in a first part of the casing area for taking out a fluid sample of the fluid present in that part of the casing area.