Abstract: A sand anchor includes a shank and a plunger. The plunger can be inserted into a first end of the shank. The plunger includes an extension, an annular fitting, and an interior seal. The extension is formed with a hollow center. The annular fitting is positioned between an outer surface of the extension and an inner surface of the shank. The interior seal is positioned within the hollow center of the extension and configured to provide a one-way seal.

Abstract: Systems, methods, and apparatuses for detecting and collecting fluids released into a body of water are disclosed. Particularly, detection and collection of a fluid released during a petroleum exploration or production operation are disclosed. A released fluid may be detected using sensors on a submersible vehicle (SV) or a plurality of SVs operating in concert. A detected released fluid is collected in storage tanks onboard of the one or more SVs or in an external tank coupled to the one or more SVs.

Abstract: Disclosed are methods and devices for testing downhole connector electrical systems and cable integrity during installation of a permanent completion, including a customized retrievable plug arm assembly connectable to the completion during RIH, the tool mimicking a retrievable ESP, but without motor, and can be employed with or without pressure isolation. Another method employs a slidable starpoint located within the downhole wet mate connector of the completion to provide continuous electrical contact between the phases when no retrievable assembly is in place. When a retrievable assembly is later put in place, the slidable starpoint is moved into a second position that no longer provides electrical contact between the phases. Another method uses fusible links installed between two conductors within the downhole electrical connector system of the completion to provide similar electrical contact between phases, the fusible link configured to melt away once motor current is sent through the conductors.

Abstract: Provided herein, is magnetic catch assembly that may be utilized with and/or incorporated into lubricator of a wellhead. The magnetic catch assembly permits maintaining a plunger within the lubricator without requiring any moving mechanical components.

Abstract: A system includes an electric submersible pump (ESP) configured for pumping fluid through a flow path. An autonomous inflow control device (AICD) is included in fluid communication with the flow path to separate one of gas or liquid out of the flow path. A method includes producing liquid from a wellbore using an electric submersible pump (ESP) in the wellbore. The method includes bypassing gas from a headspace the wellbore using an autonomous inflow control device (AICD) to prevent gas locking the ESP.

Abstract: A fishing neck for a plunger comprises a head portion, a neck portion, a lower portion, and a plurality of ribs. The head portion has a cylindrical configuration with an outer peripheral surface and an outer diameter. The neck portion also has a cylindrical configuration with an outer peripheral surface and an outer diameter, but the outer diameter is less than the outer diameter of the head portion. The neck portion extends from the head portion. The lower portion extends from the neck portion, which is opposite the head portion, and is connectable to a plunger. The lower portion has an outer diameter greater than the outer diameter of the neck portion. A plurality of ribs projects from the outer peripheral surface of the neck portion and extends helically from the head portion to the lower portion.

Abstract: An electric submersible progressive cavity pump assembly is disclosed, which includes an electric motor, a progressive cavity pump, a transmission rotatable by the motor, and a torque isolator coupled between the transmission and the progressive cavity pump, where the torque isolator includes resilient members which accommodate sudden changes in torque.

Abstract: Methods and apparatuses are provided for clearing a wellbore using a means for milling and a means for suctioning within a wellbore. Obstructions such as ball frac seats, bridge plugs, or formation material can be milled within a wellbore. As a result, larger, unrestricted, diameters can be obtained within the liner/wellbore. The cleared wellbore can allow for various remedial tools to be run into the liner/wellbore. In addition, the milled particles can be suctioned/vacuumed up and can be pumped/pushed to surface in an underbalanced fashion. In some embodiments, this can be achieved by incorporating a bottom-hole pump or a venturi component into the bottomhole assembly. The system can be deployed using a spoolable single or multi-conduit coiled tubing system and can be configured as a well intervention or work-over technology. In some embodiments, the clearing equipment can be temporary or mobile.

Abstract: A deformable cleaning element is encased within soluble packaging to maintain deformation. The deformed cleaning element is launched into the bore of a drill pipe/conduit or tubular. Contact with fluids within the bore dissolves the soluble packaging allowing the cleaning element to expand to its original shape.

Abstract: The present application includes and assembly having a hollowed body configured to traverse the length of a well bore and remove contaminants. The hollowed body having an upper seal body and a lower seal body. Each body including a seat for securing and sealing by a dart. The dart is configured to transition between the seats by passing through a central channel of the hollowed body. The dart includes a central passage and an unobstructed lower passage in the tip of the dart to allow for the direct passage of working fluid. The assembly further includes an expandable seal configured to expand in diameter from the increase in pressure in the well bore. The expandable seal contacts the walls of the well bore. The expandable seal cleans the walls of the well bore and prevents leakage of working fluid between the walls and the assembly.

Abstract: The present application includes and assembly having a rigid hollowed body and an internal dart configured to traverse the length of a well bore and remove contaminants. The body having a central channel for accepting the dart. The dart includes a central passage and an exit port to selectively permit the passage of working fluid around and through the dart. The dart is configured to transition between an extended position and a seated position. The body includes one or more restricted diameter sections to create a dampener effect to minimize and distribute the impact forces upon the assembly. The assembly optionally includes one or more external wear pads, and an expandable seal coupled to the body configured to expand in diameter from the increase in pressure in the well bore. The expandable seal contacts the walls as the assembly rises in the well.

Abstract: A tool is incorporated into a tubing string and is run into a wellbore until an agitator at a bottom of the tool engages an obstruction in the wellbore. A helical drive arrangement between a mandrel and a sleeve causes the sleeve on the outside of the tool, to which the agitator is attached, to rotate as the mandrel is reciprocated between a downstroke and an upstroke. Rotation of the agitator disrupts the obstruction forming debris therefrom and a slurry of the debris in wellbore fluid. At the same time, reciprocation of the mandrel causes a standing valve and a travelling valve in the tool to be alternately opened and closed for pumping the slurry into the tool and from the tool into the tubing string for storage therein. Periodically the tool is tripped to surface and the stored debris is removed from the tubing string.

Abstract: The present application includes and assembly having a hollowed body configured to traverse the length of a well bore and remove contaminants. The hollowed body having an upper seal body and a lower seal body. Each body including a seat for securing and sealing by a dart. The dart is configured to transition between the seats by passing through a central channel of the hollowed body. The assembly further includes an expandable seal configured to expand in diameter from the increase in pressure in the well bore. The expandable seal contacts the walls of the well bore. The expandable seal cleans the walls of the well bore and prevents leakage of working fluid between the walls and the assembly.

Abstract: A well pump assembly has a motor operatively connected to a well pump that has an intake. The well pump assembly has a capillary tube that extends alongside the tubing and has an outlet at the well pump assembly. A chemical injection pump is connected to an upper end of the capillary tube adjacent a wellhead of the well. A logic system detects well fluid falling back downward in the tubing and out the intake into the well, and in response turns on the chemical injection pump, which pumps a chemical down the capillary tube into the well adjacent or within the well pump assembly. Once upward flow of well fluid in the tubing has been established, the chemical injection pump may be turned off.

Abstract: A lower separator located below a submersible well pump intake has a labyrinth flow path, causing a first well fluid separation of lighter components from heavier components as well fluid flowing into the lower separator turns downward to flow toward a lower separator heavier component port. A bypass riser has a bypass riser inlet below the pump intake and a bypass riser outlet above the pump intake. A lighter component conduit communicates the bypass riser inlet with lighter components of the first well fluid separation, causing a second well fluid separation at the riser outlet as a heavier portion of the lighter components flowing up the riser turn to flow downward to the pump intake. A heavier component conduit bypasses the bypass riser inlet and delivers the heavier components of the first well fluid separation to the pump intake.

Abstract: A downhole apparatus comprising a body (12) configured to be coupled to a production tubular and an upper opening and a lower opening. First (28a) and second (28b) flow paths are provided between the upper opening (22) and the lower opening (24) in the body, and a flow diverter (34) is arranged to direct downward flow through the body towards the second flow path and away from the first flow path. A filter device (31) in the second flow path filters or collects solid particles in the second flow path from passing out of the lower opening of the apparatus. The apparatus has particular application to artificial lift hydrocarbon production systems, and may be installed above a down-hole pump in a production tubing to prevent solids from settling on the pump during pump shutdown. Embodiments for use with ESPs and PCPs are described.

Abstract: An apparatus is disclosed for use in a hydrocarbon production well that includes a casing extending from a segment of the production well to a wellhead. A production conduit extends inside the casing, from a first end in the hydrocarbon production well to a second end at the wellhead. A receptacle includes a bottom spaced from the first end of the production conduit and at least one sidewall extending around a portion of the production conduit proximal the first end such that the receptacle extends around the first end of the production conduit. The receptacle includes an opening for liquid to pass into the receptacle to separate liquids from gases. A submersible pump is disposed in the production well and includes a motor outside the receptacle and coupled to a pump body inside the receptacle to pump the liquid from a pump inlet in the receptacle, through the production conduit to the second end.

Abstract: A method for obtaining a fluid sample downhole that has at least a target fluid and an undesirable fluid may include receiving the fluid sample into a sample tank positioned that has a main chamber and isolating at least a portion of the undesirable fluid from the target fluid in the main chamber. A related apparatus may include a conveyance device configured to be conveyed along a borehole and a fluid sampling tool positioned along the conveyance device. The conveyance device may include a probe receiving the fluid sample from a formation; a pump drawing the fluid sample through the probe; and at least one sample tank receiving the fluid sample from the pump. The sample tank may include a main chamber receiving the fluid sample and an isolation volume isolating at least a portion of the undesirable fluid from the target fluid in the main chamber.

Abstract: An electric submersible pump assembly (ESP) (21, 120) is deployed in a production tube (20, 100) in a borehole such that the motor (26, 41, 121) of the ESP is spaced from the inner wall of the production tube, defining a conduit (36, 111) through which the pumped well fluid can flow to cool the motor. The production tube may have an enlarged diameter portion (25, 76, 101) within which the motor is positioned. Alternatively or additionally, the ESP and/or the production tube may be provided with stabilizing spacers (24, 45, 140, 141) which extend between the ESP and the tube to centralize the ESP in the tube and support it against vibrational movement, the spacers defining an annular conduit (36, 111) between the motor casing and the production tube.

Abstract: A downhole tool for removing debris from a wellbore comprises a body having a bore, a collection member, and a means for creating a hydraulic barrier within a wellbore annulus. The hydraulic barrier within the wellbore annulus restricts upward movement of a debris laden fluid within the wellbore annulus causing the debris laden fluid to be directed toward the collection member. Thus, the hydraulic barrier facilitates removal of debris from the wellbore.

Abstract: A subterranean debris catcher takes in debris laden fluid at a lower end. The inlet flow is induced with an eductor whose discharge goes around the housing to the lower end inlet for the debris. The eductor suction induces flow into the lower end of the housing as well. Incoming debris goes up an annular space around the collection receptacle and turns to pass through a bladed wheel that imparts a spin to the flowing stream. The flow direction reverses from up before the wheel to down through a tube after the wheel. The solids are flung to the tube periphery and the fluid reverses direction to go back up to a screen before reaching the eductor suction connection. The debris swirls down an open bottom tube and is collected in a housing surrounding the down tube.

Abstract: A downhole isolation tool for insertion in a wellbore, for allowing, when a ported sliding sleeve thereof is slidably positioned in a first position and when coupled to a lower end of said pump apparatus, fluids within a hydrocarbon formation to be drawn through such tool and allowed to pass to the pump apparatus for pumping uphole, and when such sliding sleeve is positioned in a second position and decoupled from said lower end of the pump assembly, for preventing said fluids from passing therethrough and uphole.

Abstract: A pump assembly for recovering hydrocarbons from downhole wells. The pump assembly comprising a seating surface adapted to sealingly engage an interior surface of a first circumferential seal means situated within production tubing when said pump assembly is in a downhole operative position. A downhole ported sleeve is further provided and comprises a first port means and a second port means. The ported sleeve is adapted to move within a seal sub comprising a lower seal means and an upper seal means. The first port means is positioned between the lower seal means and the upper seal means when the pump assembly is removed from the well, thereby preventing pressurized fluids and/or gases from reaching surface. A method for sealing a well upon removal of a pump is further disclosed.

Abstract: An apparatus and method to control and exert a predetermined force back on the wellbore thereby controlling the hydrostatic force on the formation surrounding the well-bore, the inflow of fluids from the surrounding formation and the drilling circulating medium. The apparatus comprises and the method utilizes a pump having at least one pair of intermeshing and opposite-handed helical screws disposed within a chamber for restricting the flow of well bore returns. The speed of the pump may be varied to selectively restrict the flow of well bore returns from the well bore.

Abstract: A stripper device for a wellhead defining the terminus of an aliphatic hydrocarbon production well. The stripper device includes a lubricator assembly having a lubricator pipe in communication with the wellhead and a dipper assembly traversing within the lubricator pipe and the well. A controller assembly provides instructions in a computer readable format to regulate the collection of liquid aliphatic hydrocarbons from the well with the dipper assembly. The stripper device includes a recovery assembly having a pivot element coupled to a lubricator pipe and to the wellhead. The pivot element renders the lubricator pipe to communicate with the wellhead in a first position and renders the lubricator pipe apart from the wellhead in a second position to expose the wellhead free of obstructions including those from the lubricator assembly.

Abstract: The present invention relates to an apparatus and a method for collecting debris in a wellbore.

Abstract: The present invention relates to an oil-pressure type fixed piston sampler for sampling a soil sample for site investigation. The oil-pressure type fixed piston sampler comprises a sampling unit (12) and an oil-pressure controller (14). Here, when the sampling unit (12) inserted into a drilled hole and a movable piston (80) moves downward, a sampling tube (1) moves downward to take a sample. The oil-pressure controller (14) connected with the sampling unit (12) controls oil pressure to cause the movable piston (80) to shift vertically. The sampling unit (12) comprises an upper head (20), a lower head (40), a piston housing (70), a rod block (100), a movable rod (90), a fixed piston (110), a fixed rod (92) and a separation rod (94). Since the sampling tube (1) takes a sample by a piston indentation method, high-quality, undisturbed samples can be obtained.

Abstract: An apparatus includes a frame structure and one or more fracking fluid tanks carried by the frame structure. The one or more fracking fluid tanks arranged to contain a fracking fluid usable during a fracking procedure. One or more fracking pumps may be carried by the frame structure, the one or more fracking pumps being configured to pump the fracking fluid to a wellhead of a wellbore at high pressure. An integrated piping system connects with the one or more fracking pumps to carry fracking fluid that was contained in the one or more fracking fluid tanks toward the one or more fracking pumps. Mobility-enabling structure supports the frame structure, the one or more fracking fluid tanks, the one or more fracking pumps, and the integrated piping system, the mobility enabling-structure being configured to enable conveyance of the apparatus to a fracking site.

Abstract: In one aspect, an apparatus for use in a wellbore formed in a formation is disclosed that in one embodiment includes a device for supplying a hydraulic fluid under pressure to a common hydraulic line, a first pump in hydraulic communication with the common hydraulic line via a first variable fluid control device, a second pump in hydraulic communication with the common hydraulic line via a second variable fluid control device, and at least one controller that controls flow of the hydraulic fluid from the first variable flow control device to the first pump and the flow of the hydraulic fluid from the second variable flow control device to the second pump to independently control the operation of the first pump and the second pump. In another aspect, the first pump is coupled to a first probe for extracting fluid from the formation and the second pump is coupled to a second probe for extracting the fluid from the formation.

Abstract: In one aspect, an apparatus for obtaining a fluid from a formation is disclosed that in embodiment may include a fluid extraction device that extracts the fluid from the formation into a first fluid line, a sample chamber coupled to the first fluid line via a second fluid line that receives the fluid from the first fluid line, wherein the first fluid line and the second fluid line receive contaminated formation fluid when the fluid extraction device initially extracts the fluid from the formation, and a fluid removal device associated with the second fluid line for receiving at least a portion of the contaminated formation fluid from the second fluid line.

Abstract: An apparatus and method for delivering a thickened fluid mixture, including a CO2 recapture system. The apparatus including a proppant storage vessel and a fracturing fluid storage vessel providing a continous supply of a proppant material and a fracturing fluid to a mixing apparatus. The mixing apparatus configured to output and deliver a thickened fluid mixture of the proppant, the fracturing fluid and a thickener agent at or above the fracturing fluid blending pressure to a high pressure pump assembly. The high pressure pump assembly configured to deliver a high pressure thickened fluid mixture to one or more downstream components at an injection pressure. The apparatus including a CO2 recapture system configured to recapture an exhaust stream from the one or more downstream components and/or other CO2 output sources, and provide a purified and liquefied CO2 fluid stream to the fracturing fluid storage vessel. The apparatus configured for continual operation.

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: Device for lining the wall of a wellbore as it is being drilled using a drill string having a drill bit on the lower end thereof. The device has a receptacle for a cylindrically gathered pack of flexible tubing capable of being supported around the outside of the drill string near the lower end thereof on a plurality of bearings, a radially expandable locking device attachable to one end of the flexible tubing and being capable of being expanded against the wellbore wall to lock the end of the flexible tubing in place in the wellbore, and a conduit having an inlet upstream of the receptacle and an outlet downstream of the receptacle. A pump is located in the conduit or abutting the inlet or outlet thereof, and pumps the drilling fluid so that a fluid pressure inside the liner is greater than a fluid pressure at the drill bit.

Abstract: A piston assembly may comprise a housing with a wall, and at least one chamber formed in the wall. A piston may be disposed within the chamber and at least one passageway may pass through the piston. At least one pin may be disposed within the passageway and attached to the chamber, and the piston may be free to translate relative to the pin.

Abstract: Systems, devices, and methods of producing a fluid include a pump assembly that operates to increase the hydrostatic pressure of the fluid. The pump assembly is located in a well completion below a formation isolation valve. The pump assembly releasably connects to a polished bore receptacle in the well completion.

Abstract: An electric submersible pump (ESP) assembly comprises an integrated sub-assembly encased within a shroud. The integrated sub-assembly comprises a downhole monitoring gauge, a motor, a well fluid intake, a seal section, a mounting member, and an electrical conduit extending between the mounting member and the motor. The intake has a plurality of intake slots positioned a select distance from the mounting member in order to minimize the space for the accumulation of gas within the shroud. The electrical conduit sealingly extends through the mounting member to a receptacle located on an upper portion thereof. Conductors are encased within the conduit and are connected between the receptacle and the motor. The conduit prevents the conductors from being affected by reservoir fluid and pressures.

Abstract: A system and method are provided for collecting fluid samples from a fluid flowline located subsea. The system includes a multiphase sampling apparatus attachable to the flowline, and a vehicle sampling apparatus that is connectable to the multiphase sampling apparatus to allow the transfer of the collected fluid sample thereto. The vehicle sampling apparatus is preferably a subsea remotely operated vehicle (ROV) locatable proximate the fluid flowline and having a fluid sample collector and a fluid pump for transferring the collected fluid sample from the multiphase sampling apparatus to the fluid sample collector. The vehicle sampling apparatus includes a fluid analysis sensor capable of extracting information about the collected fluid sample at a subsea location. Optionally, the vehicle sampling apparatus can transport the collected fluid sample to a location remote from the fluid flowline for analysis.

Abstract: An electric submersible pump (ESP) assembly comprises an integrated sub-assembly encased within a shroud. The integrated sub-assembly comprises a well fluid intake having a shroud hanger formed in an upper portion thereof, a seal section having a motor head formed in a lower portion thereof, and an electrical conduit extending between the shroud hanger and the motor head. The intake has a plurality of fluid entry slots positioned a select distance from the shroud hanger in order to minimize the space for the accumulation of gas within the shroud. The electrical conduit sealingly extends through the shroud hanger to a receptacle located on an upper portion thereof. Conductors are encased within the conduit and are connected between the receptacle and the motor head. The conduit prevents the conductors from being affected by reservoir fluid and pressures.

Abstract: An apparatus and method is disclosed for conducting a fluid and solids production test in a subterranean well. A testing apparatus may be inserted into a wellbore. The apparatus may employ a tubular housing with entry port(s) through the housing. An inner assembly may be positioned within the tubular housing, the inner assembly being configured for connection to the tubular housing. The inner assembly may include a fluid permeable screen and a distal end forming a reservoir that is scaled, or may be adapted to be scaled, for the collection of solids during a well production testing event. Following a testing event, the apparatus may be removed from the wellbore to enable the collected solids to be measured to determine the amount of solids generated by a subterranean formation at actual field flow conditions.

Abstract: A method for determining wettability of a solid, such as a reservoir rock material, is described. The method includes disaggregating the material, for example by grinding and placing the disaggregated material on the surface of the fluid. The wettability is analyzed based on whether a portion of the material floats on or sinks into the fluid. The method is well suited for heterogeneous solid materials that have mixed wetting characteristics and/or have varying surface types. The fluid can be evaluated as a potential treatment fluid or a component thereof that can be used for treating the rock formation. For example, the potential treatment fluid can include a surfactant or an oxidizing agent. A simple observation can be made whether substantially all of the material placed on the surface of the fluid sinks into the fluid, or the portions of floating and sinking material can be weighed.

Abstract: The present invention relates to an oil-pressure type fixed piston sampler for sampling a soil sample for site investigation. The oil-pressure type fixed piston sampler comprises a sampling unit (12) and an oil-pressure controller (14). Here, when the sampling unit (12) inserted into a drilled hole and a movable piston (80) moves downward, a sampling tube (1) moves downward to take a sample. The oil-pressure controller (14) connected with the sampling unit (12) controls oil pressure to cause the movable piston (80) to shift vertically. The sampling unit (12) comprises an upper head (20), a lower head (40), a piston housing (70), a rod block (100), a movable rod (90), a fixed piston (110), a fixed rod (92) and a separation rod (94). Since the sampling tube (1) takes a sample by a piston indentation method, high-quality, undisturbed samples can be obtained.

Abstract: An apparatus and process for gas, oil, and other fluid production using bailer technology with stimulation to enhance production. An enclosed apparatus and process for removing gas, oil, and/or other fluids from a well while reducing environmental impact. A novel divalve for simultaneously closing a conainer and dumping liquids into it.

Abstract: A sample tank for receiving and storing sampled connate fluid from a subterranean geological formation. The sample tank includes a piston coaxially disposed within the tank. The piston can be disposed close to the end of the tank where the sampled fluid is introduced into the tank and urged along the length of the tank as sampled fluid is added to the tank. The piston includes an agitator for mixing the fluid and keeping particulates suspended within the fluid. The agitator includes a magnetic member, and is rotated by applying a varying electromagnetic field to the member.

Abstract: Production logging apparatus and method are provided. The apparatus comprises a coupling module, an electronic module, a micro-winch, a docking station, and a micro-production logging tool. The coupling module provides mechanical support for the production logging apparatus below a pumping arrangement disposed in a wellbore, and allows flow to enter the pumping arrangement. The electronic module comprises a winch controller, a powering module and a telemetry module, and adapted to automate the micro-winch. The docking station comprises a latching mechanism for ensuring positive engagement of a micro-production logging tool with the production logging apparatus during docking. And the micro-production logging tool comprises at least one sensor and is coupled to the micro-winch by a cable for regular production logging runs to measure the evolution of well characteristics.

Abstract: A rotary pump having thrust bearings includes a system for equalizing the loading on the thrust bearings. The thrust bearings are each supported on pistons that are in fluid communication with a hydraulic circuit. The hydraulic circuit has substantially the same pressure throughout, thereby floating each piston at the same pressure to provide an equal support force to each thrust bearing via each piston.

Abstract: An apparatus and methods for pumping a fluid mixture from a wellbore location to a selected location is disclosed. The apparatus, in one embodiment, includes a container configured to be placed in the wellbore, wherein the container is configured to mix therein a fluid received from a first source and an additive received from a second source, and a pump unit coupled to the container and configured to pump the mixed fluid from the container to the selected location. The method in one embodiment includes: supplying a fluid from a first source to a container placed in a wellbore; supplying an additive from a second source to the container; allowing the fluid and the additive to mix in the container to form a mixed fluid; and pumping the mixed fluid from the container to the selected location.

Abstract: A system that includes a plurality of heat sources configured to heat a portion of a formation is described. At least one production well is in the formation. A bottom portion of the production well is a sump in an underburden of the formation below the heated portion of the formation. Fluids from the heated portion of the formation are allowed to flow into the sump. A pump system has an inlet in the sump. A production conduit is coupled to the pump system. The production conduit is configured to transport fluids in the sump out of the formation.

Abstract: An electrical wireline conveyed baling system for removing large volumes of liquids from a well borehole with a single trip of a bailer tool string. The system also utilizes one or more blow out preventers thereby allowing wireline bailing operations to be carried out while controlling well pressure. A bailer tool string that is conveyed by the wireline comprises a tool head containing a pump, at least one carrier section, and a no-return valve. Once deployed in the borehole, a first signal transmitted via the wireline from the surface activates the pump thereby reducing pressure within the carrier section. A second signal transmitted via the wireline from the surface opens the no-return valve thereby allowing liquid to flow from the borehole into the carrier section. The bailer tool string containing liquid is subsequently retrieved via the wireline thereby removing liquid from the borehole.

Abstract: A method of producing a well utilizes a submersible pump run on a line, such as braided wire rope, that includes power conductors. The operator sets a packer in the casing, the packer having a check valve and a tieback receptacle. The operator pressure tests the integrity of the casing above the packer, and if it passes, then runs the pump assembly on the line. The pump assembly has a shroud with a downward extending extension that seals to the passage of the packer. If the pressure test of the casing fails, the operator runs a liner into the well and engages the tieback receptacle. A smaller diameter pump is then lowered on a line into the liner and into engagement with the packer.

Abstract: An oil and gas well production unit for the retrieval of oil and gas from a diminishing oil and gas production field. The unit comprises a well casing within the field attached to a lubricator assembly. A plunger is arranged for reciprocable travel within a tubing in the casing and the lubricator to assist in the production of oil and gas removal from the oil and gas well production unit. A plunger examination port is arranged within the lubricator assembly to permit determination of the amount of wear of the plunger without having to remove the plunger from the lubricator assembly.