Abstract: The present disclosure describes a wellhead system that includes a wellhead; a tank of corrosion inhibitor chemical; and an ejector device comprising: a high pressure nozzle connected to the wellhead through a first flowline; a low pressure nozzle connected to the tank of corrosion inhibitor chemical through a second flowline; and wherein the ejector device is configured to generate a gas and chemical mixture fluid that exits the ejector device and flows downstream of the wellhead system.

Abstract: A hydraulic fracturing system can include valve apparatuses that control the delivery of fluid to high-pressure pumps that supply the fluid to a wellhead. The valve apparatuses can receive electronic signals from a control system to regulate the flow rate of the fluid to the high-pressure pumps. In one or more examples, the flow rate of the fluid can be controlled such that proppant in the fluid remains in solution.

Abstract: A wellhead system includes a wellhead, a fluid line extending from the wellhead, a branch line fluidly connected to the fluid line at an inlet and at an outlet, an ejector device arranged on the branch line, a tank fluidly connected by a tank fluid line to the ejector device, and a pressure control valve arranged on the branch line upstream of the ejector device. The ejector device is configured to produce a mixture that includes the fluid from the wellhead flowing in the branch fluid line with a chemical flowing the tank fluid line. The ejector device is also configured to discharge the mixture downstream of the ejector device. The pressure control valve is configured to control the flow of a fluid entering the ejector device.

Abstract: A gooseneck pipe includes a first pipe half having a first radiused centerline curve, and a second pipe half fixed to the first pipe half and having a second radiused centerline curve. The first and second pipe halves define a flow path. Cross-sectional diameters of the first and second pipe halves vary along the flow path. The varying diameters of the first and second pipe halves serve to mitigate pressure losses due in part to Dean vortices or secondary flow patterns in the flow path when a fluid is turned in the gooseneck pipe.

Abstract: A system and method for delivering a treatment fluid to a wellbore by emulsifying the treatment fluid with a continuous fluid in a flowline. The treatment and continuous fluids are combined in a mixer that is separate from containers that retain the fluids. In an example where the mixer is a venturi, the continuous fluid flows into an inlet on an entrance end of the venturi, and the treatment fluid flows into an inlet that is at a flow restriction in the venturi. The continuous fluid experiences a localized decrease in pressure at the restriction, which is due to a localized increase in flow rate at the restriction. The pressure decrease induces the treatment fluid into the venturi, where the treatment fluid is dispersed into droplets within the continuous fluid, and that forms a treatment emulsion. The treatment fluid escapes from within the treatment emulsion when in the wellbore.

Abstract: A downhole tool includes a circumferential band having a plurality of axially adjacent weld beads forming a wear resistant surface along a particular axial length of the tool and at least one circumferential multi-layer coating applied axially adjacent the band on either end. The multi-layer coating includes a first layer, exhibiting a first color, applied directly onto the tool surface, and a second wear-resistant layer, exhibiting a second color different from the first color, applied directly onto the first layer. The second layer wears or is removed by a certain amount, such that the first color of the first layer is revealed to indicate the extent of wear and/or that the tool should be removed from service and refurbished by applying a new wear-resistant coating.

Abstract: This disclosure includes anti-reverse rotation apparatuses, rotors for use therein, and related methods. Some apparatuses include a stator defining an interior volume and one or more arcuate contact surfaces within the interior volume, and a rotor rotatably coupled to the stator and at least partially disposed within the interior volume, the rotor having a hub, two or more shoes, each pivotally coupled to the hub and extending between a first end and a second end that is farther from the hub than is the first end, wherein each of the shoes is rotatable relative to the hub between: (a) a first position in which the second end of the shoe contacts at least one of the arcuate contact surface(s) of the stator; and (b) a second position in which the second end of the shoe does not contact the arcuate contact surface(s) of the stator.

Abstract: An improved free piston assembly for use in combination with a plunger lift assembly is provided. The piston assembly includes a sleeve member, a retention sleeve, and a flow restriction member. The sleeve member has an inner surface defining an opening for the flow of formation fluids. The opening includes a first section and a second section. The retention sleeve is configured to be affixed to the first section of the opening. The flow restriction member is not latched to the sleeve member and is configured to have an interference fit with the retention sleeve. The interference fit provides a force that is sufficient to overcome the force of gravity on the flow restriction member when formation fluid forces acting on the flow restriction member are decreased or removed. The second section of the opening is configured to prevent the passage of the flow restriction member.

Abstract: An automatic release valve assembly for a bumper spring, comprising a hollow cylindrical valve seat sleeve having a plurality of flow ports and flow passages disposed in the sidewalls thereof; a valve ball sized to engage by contact with a robust valve seat; a multiple coil spring disposed over the sleeve portion of the valve seat sleeve; wherein the valve seat sleeve, ball, and coil spring are enclosed within a hollow cylindrical housing. The housing includes within its bore a central region of a plurality of parallel, elongated and interleaved grooves and ridges to permit released fluid to flow and to stabilize the operation of the valve assembly.

Abstract: A bypass plunger combines a unitary or one-piece hollow body-and-valve cage, retains a dart valve within the valve cage portion of the hollow body using a threaded retaining nut secured by crimple detents. A series of helical grooves surround the central portion of the outer surface of the hollow body of the plunger to control spin during descent. A canted-coil-spring disposed within the retaining nut functions as a clutch. The valve cage includes ports that may be configured to control flow through the plunger during ascent. Other embodiments include clutch assemblies using canted-coil springs with split bobbins, and valve stems surfaced to achieve specific functions.

Abstract: Systems, program product, and methods for monitoring linearity of a down-hole pumping system assembly during deployment within a bore of a casing of a well positioned to extract hydrocarbons from a subterranean reservoir and selecting an optimal operational position for the down-hole pumping system assembly within the bore of the casing, are provided. Various embodiments of the systems allow an operator to ensure that a motor and pump of a down-hole pumping system assembly are installed in an optimal position in a well by ensuring alignment across the pump stages casing and motor casing. The system includes a groove extending along an outer surface of a housing of the pumping system assembly, and an optical sensing fiber mounted in the groove.

Abstract: Gas lift plungers and methods are provided. The gas lift plunger includes a body including a first end, a second end, a valve seat extending from the first end, and a bore extending between the valve seat and the second end. The gas lift plunger also includes a valve element configured to be received through the bore. The valve element includes a first end, a second end, and a valve-engaging portion extending radially outward from a main portion of the valve element. The valve element is movable in the bore between an open position and a closed position. In the closed position, the valve-engaging portion engages the valve seat, and the valve element extends through the second end of the. Further, in the open position, the valve-engaging portion is separated from the valve seat, allowing fluid communication through the bore.

Abstract: A downhole pumping assembly has a tubing string with plural barrels which are arranged in-line with the tubing. The tubing string has a seating location adjacent to each barrel. A standing valve arrangement, which includes a standing valve and a seating device, is located with the standing valve adjacent to the lower end of one of the barrels. A plunger has a traveling valve that is located for reciprocation within the one barrel. The plunger has a clearance with each of the barrels so as to form a fluid seal. The plunger reciprocates inside the barrel so as to lift fluid to the surface. Over time, the barrel will exhibit wear. Instead of pulling the entire tubing string to replace the barrel, the standing valve and the plunger are relocated to one of the other barrels located in the tubing string and reciprocation is resumed to resume pumping.

Abstract: An apparatus for restricting movement of sand in an oil well has a production tubing, a working barrel positioned in the production tubing, a tubular member affixed an end of the working barrel, and a seal extending around the tubular member. The seal is of an elastic or an elastomeric material. The seal has an outer periphery contacting the inner diameter of the production tubing. The seal has a plurality of splits formed therethrough. Each of the splits has a generally V-shaped configuration.

Abstract: A shearing mechanism in which a male component mates into a female component, the male component having a first groove extending around the male component and the female component having a second groove extending around the female component, the first groove and the second groove cooperating when the male component is inserted into the female component to define an annular recess. A shearing component is provided within the annular recess, the shearing component having a shear load that is controlled by the material and size of the shearing component. An opening is provided within one or both of the male component and female component, the opening being aligned with the annular recess. Stress relief is provided.

Abstract: A wellbore pump includes a pump housing suspendible in a wellbore at ends of at least one of a power fluid line and a fluid discharge line. The pump housing includes a fluid inlet proximate a bottom end thereof and wherein the fluid discharge line is coupled proximate a top end thereof. The pump include valves for directing flow of wellbore fluid out of the housing when power fluid displaces fluid in the housing, the valves for directing flow of wellbore fluid into the housing when power fluid pressure is relieved.

Abstract: A system is described that provides for proppant to be blended into a liquefied gas fluid stream with an eductor to produce a proppant slurry which is effectively controlled by the use of a control valve system and associated PLC controller. This system ensures allowing for operation of the system at various static pressures and keeps the proppant completely fluidized throughout the fracing operation.

Abstract: In various exemplary embodiments, the present disclosure relates to a flow divider in a spool for a pitless adaptor included in a booster station and/or well construction. The flow divider has a generally triangular shaped cross-section that efficiently helps direct water flow from a vertical to a horizontal direction reducing pressure head lost in the spool and thereby increasing the energy efficiency of the system. In various exemplary embodiments, the flow divider may have a variety of cross-sectionals shapes and sizes depending on the size and requirements of the well or booster station.

Abstract: An oil well pumping apparatus for pumping oil from a well to a wellhead provides a tool body sized and shaped to be lowered into the production tubing string. A working fluid is provided that can be pumped into the production tubing, by a prime mover. 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, including upper and lower spur gear or gears connected with a common shaft. The upper spur gear is driven by the working fluid. The lower spur gear is rotated by the first spur gear. The tool body has flow conveying portions that mix the working fluid and the produced oil as the oil is pumped.

Abstract: A beamless mechanic-reversing long stroke pumping unit is provided for petroleum production in diverse types of oil fields. Its mechanic-reversing system consists of differentials, brakes, etc. With two differentials assembled together, taper gears inside them perform revolution and rotation, enabling the pumping unit to achieve direction change and speed change mechanically. The stroke length of the pumping unit can reach 8 meters or longer, and the adjustment process is more convenient than most, by merely tuning the position of the proximity switches. Abrasion of the chains typically caused due to resetting of a motor frequently during operation, is eliminated in this pumping unit. The pumping unit has more reliable operation performance, more convenient maintenance, lower costs, better energy saving effects, and can be applied in land oil fields, offshore oil fields, oil wells with low permeability, etc.

Abstract: A method of implementing a substitute for a pump-off controller in a downhole production string, the method including locating a pump and a valve in the production string wherein capabilities include the pump pumping a reservoir product through the valve, the valve transitioning to a bypass mode, and the valve interrupting a reservoir product flow.

Abstract: Systems, program product, and methods for monitoring linearity of a down-hole pumping system assembly during deployment within a bore of a casing of a well positioned to extract hydrocarbons from a subterranean reservoir and selecting an optimal operational position for the down-hole pumping system assembly within the bore of the casing, are provided. Various embodiments of the systems allow an operator to ensure that a motor and pump of a down-hole pumping system assembly are installed in an optimal position in a well by ensuring alignment across the pump stages casing and motor casing. The alignment and linearity of the pump and motor can be crucial to run life of the pump and/or motor.

Abstract: A system for removing liquids from an inclined wellbore includes a plug member positioned within a heel section of the inclined wellbore, the plug member including an orifice therethrough; a first tubular member having a first end for providing fluid flow from the first portion of the wellbore to the second portion of the wellbore, a second end positioned at least partially within the second portion of the wellbore and providing fluid flow from the first portion of the wellbore to the second portion of the wellbore; a second tubular member positioned within the second portion of the wellbore, the second tubular member having a first end for receiving fluid from the second portion of the wellbore, the second end positioned adjacent the surface of the inclined wellbore; and a pump for pumping fluid from the second tubular member to the surface.

Abstract: A crude oil lifting system and a method utilizing a vane pump for conveying a fluid. The crude oil lifting system comprises: an oil pipe and an oil pump connected to the oil pipe. The oil pump is the vane pump. The vane pump is provided with a cylindrical stator. The stator has arranged therein a drive shaft and a rator sleeved onto the drive shaft. The drive shaft is arranged within the stator along the direction parallel to the length of the stator. An intake plate is arranged at the lower end of the stator. A discharge plate is arranged at the upper end of the stator. The intake plate, the discharge plate, and the stator form a cylindrical cavity. The rotor is arranged between the intake plate and the discharge plate. An intake opening for taking in the crude oil is arranged on the intake plate. A discharge opening for discharging the crude oil is arranged on the discharge plate.

Abstract: A counterweighted well pumping unit comprises two or more reversible motors, each of which is directly and operatively connected to a rotatable drive component mounted on a support structure positioned over a wellhead. For each motor, an elongate, flexible drive element is trained over the associated rotatable drive component, with one end of the flexible drive element connected to a counterweight assembly and the other end connected to a pump rod string associated with the wellhead. Actuation of the motors rotates the rotatable drive components, thus causing the drive elements to move the pump rod string and the counterweight assembly in opposite vertical directions. The rotational direction of the drive motors is alternated so as to alternate the directions of vertical movement of the pump rod string and the counterweight. The counterweight assembly may be concentric with or offset from the wellhead.

Abstract: A submersible well pump assembly has a rotary pump, a motor, and a seal section coupled between the motor and the pump. The seal section has a cylindrical housing having upper and lower adapter and a shaft extending axially through the housing. A guide tube surrounds the shaft and a bellows surrounds the guide tube. A well fluid passage communicates well fluid to a well fluid chamber between the bellows and the housing. A guide tube passage extends axially within the guide tube between an interior and an exterior of the guide tube from an upper portion to a lower portion of the guide tube for communicating lubricant in the motor with lubricant within the bellows.

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: An apparatus, system and method for reducing gas intake in horizontal submersible pump assemblies are described. A horizontal electric submersible pump (ESP) system for pumping gaseous fluid comprises a multi-stage centrifugal pump, an electric motor operatively coupled to the centrifugal pump, and an intake section upstream of the pump comprising a tapered core further comprising a sloped outer surface extending between a downstream side and an upstream side, a first intake port for the intake of well fluid in an ESP assembly, the first intake port located on a top portion of the tapered core and proximate to the downstream side, a gravity-actuated closing member moveably attached on the sloped outer surface, wherein the gravity-actuated closing member closes the first intake port, and a second intake port located on a bottom portion of the tapered core, the second intake port open to the well fluid.

Abstract: An electric submersible pump (“ESP”) module is disclosed for producing fluids from subsea wells. The ESP module includes at least two ESPs positioned side by side and connected in parallel to discharge into a common manifold. The ESPs and manifold can be enclosed in a housing and deployed to a subsea location. At the subsea location, the ESP module can be operationally connected to an electric source, the production fluid, and to an export conduit. The production fluid from the well(s) is drawn from within the housing into one or more of the at least two ESPs which energize and discharge the production fluid into the manifold and through the export conduit to a collection point. Each of the ESPs may be selectively operated to provide the desired flow rate and/or lifting head.

Abstract: A plunger system for maximizing the liquid lift potential of a plunger arranged for vertical travel in a conduit in a gas/oil production well. The plunger system comprises an elongated plunger body mandrel having an upper or first end and a second or lower end with a fluid transmitting bore extending longitudinally therethrough, from the second or lower end of the plunger body and into at least a central portion of the plunger body, a plurality of curvilinearly shaped, replaceable wear pads arranged in a controllably radially displaceable manner on the plunger body, and at least one fluid ejecting nozzle arranged extending through a side wall of the plunger body.

Abstract: A plunger lift control system for improving the output efficiency of an oil or gas well by a real-time reporting arrangement, the system comprising: a tubing string having an upper end and a lower end, the tubing string arranged within a well casing for receiving a plunger traveling therethrough, a plunger having a sound generating function therewith, so as to transmit a real-time lower-end location signal from the plunger to a signal sensor and processor arranged in communication with a system controller arranged at the upper end of the tubing.

Abstract: A jet pump and method of using the jet pump for removing fluids and solids from a conduit. The jet pump is adapted for use with a spoolable multi-string tubing system. The jet pump may be deployed rapidly and is suitable for temporary installation. The method may be used to reestablish flow in watered out and sanded off wells, or to test wells. The jet pump is adapted to remove wellbore fluid, which may be removed in combination with power fluid. The spoolable multi-string tubing system includes two or more substantially parallel conduits, allowing power fluid and return fluid to flow in separate conduits. Preferred embodiments provide additional functionality by inclusion of jetting elements, sensing elements, back-pressure valves, and auxiliary tubing strings or communication members in the spoolable multi-string tubing system.

Abstract: The disclosed invention provides intelligent adaptive control for optimization of production output, energy efficiency and safety of a linear reciprocating long stroke hydraulic lift system, for use at the surface of oil and gas wells to extract fluids or gas after free flowing stopped due to natural decline of reservoir pressure. The hydraulic pump and its adaptive control system introduced in this invention are capable of optimizing its production capacity by varying multiple operating parameters, including its stroking length and speed characteristics continuously and instantaneously at any point. Merits and benefits of this invention include significant increase in production efficiency, improved durability and longevity of the pumping equipment, significant power consumption savings and an ability to adapt effectively to changing well conditions.

Abstract: The present disclosure relates to a fiberglass rod with connectors on each end. Each connector has a rod-receiving receptacle having an open end, a closed end, and axially spaced annular wedge shaped surfaces such that the compressive forces between the rod and the respective connector are defined by the shape of the wedged surfaces.

Abstract: A well conveyance system couples to an uphole end of an artificial lift system and operates to push the artificial lift system through a tubing string for deployment in a wellbore. The well conveyance system includes a wellbore tractor adapted to push the artificial lift system through the tubing string and a swab cup assembly having a swab cup and a perforated nipple extending therethrough. The perforated nipple includes a nipple passage allowing for fluid flow from an area downhole from the swab cup to an area uphole from the swab cup when the wellbore tractor operates. A valve selectively blocks the perforated nipple to permit a hydraulic pressure to be applied to the tubing string uphole of the swab cup, exerting a downhole force on the swab cup to aid in deployment of the artificial lift system.

Abstract: A variable volume modular well plunger with fishing neck segment having an upper fishing neck receiver and a lower threaded receiver and defining therebetween an annular chamber, at least one extension segment having a first end threadedly engaging the lower threaded receiver and a second end and defining therebetween an extension annular chamber communicating with the fishing neck annular chamber; and an end means for sealing chamber; a loading means for charging a treatment material; a means for deploying the plunger into a well bore; and a means for diffusing the treatment material at a desired position in the wellbore. Surface treatments adapted to provide at least one desired characteristic interaction between the plunger and tubing through which it passes selected from the group of wear pads, spiral brushes, non-sprial brushes, wobble washers, grooved surface, and interlocking expandable may be used alone or in any combination of multi-surface configurations.

Abstract: The present invention discloses apparatuses, systems, and methods for operating a gas well. Some embodiments include a plunger apparatus configured to fall through a continuous water phase (including water slugs) in a gas producing well by overcoming pressure and drag forces from the water by having a sufficient mass, hydrodynamic profile, and sufficiently large area for passage of the continuous water. In one embodiment, a plunger body and plug mechanism are provided, wherein the plug mechanism has open and closed positions, which may be automatically changed or controlled by a surface or other control system, and wherein the plunger body and plug may be a physically integrated one-piece system, or an interoperable two piece system.

Abstract: A method of servicing a wellbore, comprising establishing a pumping profile having a performance plan, operating a first pump according to a first pumping parameter value, and operating a second pump according to the second pumping parameter value, wherein the second pumping parameter value is selected relative to the first pumping parameter value to improve a conformance of a phase sensitive combined pump effect operational characteristic to the performance plan. A wellbore servicing system, comprising a pump group comprising a plurality of plungers wherein at least some of the plurality of plungers are substantially configured according to an equal phase angle distribution arrangement.

Abstract: A system and method for removing liquid from a horizontal wellbore is disclosed. The system and methods utilize multi-conduit tubing associated with one or more liquid intake port(s) and vent port(s) positioned at selected locations along the tubing and positioned within a wellbore. The one or more liquid intake ports are placed at liquid accumulation points along the primarily horizontal section of the wellbore. The one or more vent housings are placed at gas accumulation points along the primarily horizontal section of the wellbore. Various embodiments of intake port are also disclosed.

Abstract: The present invention is directed to methods for extracting fluids from oil and gas wells. More specifically, it is directed toward methods and apparatuses to power and control down hole hydraulic devices using subterranean centrifugal pumps. This invention represents a vast improvement over current hydraulic artificial lift systems. This invention provides for safe, efficient, and increased fluid recovery of oil and gas reserves from subterranean reservoirs in all types of wells, including deviated and horizontal wells.

Abstract: A system for disengaging a power supply at the surface of a well from a downhole assembly having a pump for pumping fluid in the well to the surface thereof. A captured spline assembly interposed in the rod string, selectively connected to the downhole assembly to provide torsional drive.

Abstract: A system for connecting and disconnecting a rod string from a downhole assembly in which a captured spline assembly is encased in a receiver attached to the downhole assembly and an on-off tool separating the rod string from the downhole assembly.

Abstract: Disclosed are lost circulation treatment fluids and methods of sealing lost circulation zones. Embodiments include a method of sealing a lost circulation zone. The method comprises circulating a lost circulation treatment fluid in a wellbore, wherein the lost circulation treatment fluid comprises: pumice, hydrated lime, a set retarder, and water; and allowing the lost circulation treatment fluid to set in the lost circulation zone to seal the lost circulation zone.

Abstract: The invention relates to a double string slurry pump for pumping liquids to the surface of a hydrocarbon well and especially a hydrocarbon well that is producing both natural gas and liquid fluids. The double string slurry pump includes a hollow tube that raises and lowers the plunger and carries the liquids to the surface and an outer tube receives liquids down into the well to periodically flush area around the pump to stir up particles and fines for conveyance out of the wellbore with the liquids. The additional conduit for flushing may be used to provide biocides, solvents or other treatments including with liquids at elevated temperature to create desired results or changes downhole. Moreover, the additional conduit may be provided with ports to provide access to the interior of the gas production path to provide such treatments above the well. The natural gas is produced through the annulus between wellbore casing and the outer production tubing string.

Abstract: A pumping system includes a submersible high speed electric motor operable to rotate a drive shaft; a high speed pump rotationally fixed to the drive shaft; an isolation device operable to expand into engagement with a tubular string, thereby fluidly isolating an inlet of the pump from an outlet of the pump and rotationally fixing the motor and the pump to the tubular string; and a cable having two or less conductors, a strength sufficient to support the motor, the pump, and the isolation device, and in electrical communication with the motor. A maximum outer diameter of the motor, pump, isolation device, and cable is less than or equal to two inches.

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: An oil well includes a wellbore (2), below ground level (4), which extends to an oil reservoir (6). The wellbore includes a casing (8) within which is arranged a progressing cavity pump (PCP) 10 which includes an inlet (12) at its lower end and is connected at its upper end to production tube (14). An annulus (16) is defined between the pump (10)/tube (14) and the casing (8). The annulus communicates with the reservoir and includes a head (20) of reservoir fluid. A water based formulation which comprises an optionally cross-linked polyvinylalcohol can be poured down the annulus (16) and pass under gravity to the reservoir (6), immediately upstream of inlet (12). The formulation may improve the performance and efficiency of the pump (10) due to its ability to increase the mobility of the oil in the reservoir immediately upstream of the pump (10) and/or enhance the ability of the oil to enter the pump inlet.

Abstract: Methods and mechanisms for fluid sealing are provided. The disclosed mechanisms include a tool having a cavity configured to form a toroidal vortex and a fluid sealing element to induce an azimuthal variation of the toroidal vortex (a “dynamic seal”). The fluid sealing element may include a sharp change in the axial symmetry of the cavity to induce the azimuthal variation. Some exemplary shapes of the fluid sealing element may include a notch in a cavity, a step shaped cavity, or an angular cavity in the tool. Methods for manufacturing such a dynamic seal is also provided as well as methods for producing hydrocarbons with a plunger having the dynamic seals. The tool may be a plunger, a pig, an in-flow control device, or other cylindrical device traveling through a conduit or tubular member.

Abstract: A double string pump transports liquids to the surface of a hydrocarbon well including a hydrocarbon well that is producing both natural gas and liquid fluids. The double string pump includes a hollow tube that raises and lowers the plunger and carries the liquids to the surface and an outer tube receives liquids down into the well to lubricate the moving parts and flush particles from areas prone to wear and back toward the production tube. The natural gas is produced through the annulus between wellbore casing and the outer production tubing string.

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.