A high voltage generation circuit is disclosed, which includes a battery for providing a first direct current voltage, a first inductance connected in series with the battery, a power switch and a voltage multiplier. The power switch is configured for converting the first direct current voltage to a pulse voltage. The voltage multiplier is configured for multiplying the pulse voltage to a second direct current voltage. The second direct current voltage is higher than the first direct current voltage. The voltage multiplier includes super capacitors which are connected in series. A high voltage generation method is also disclosed.
H02M 3/07 - Conversion of dc power input into dc power output without intermediate conversion into ac by static converters using resistors or capacitors, e.g. potential divider using capacitors charged and discharged alternately by semiconductor devices with control electrode
A high voltage generation circuit is disclosed, which includes a battery for providing a first direct current voltage, a first inductance connected in series with the battery, a power switch and a voltage multiplier. The power switch is configured for converting the first direct current voltage to a pulse voltage. The voltage multiplier is configured for multiplying the pulse voltage to a second direct current voltage. The second direct current voltage is higher than the first direct current voltage. The voltage multiplier includes super capacitors which are connected in series. A high voltage generation method is also disclosed.
H02M 3/07 - Conversion of dc power input into dc power output without intermediate conversion into ac by static converters using resistors or capacitors, e.g. potential divider using capacitors charged and discharged alternately by semiconductor devices with control electrode
A pump for use in a motorized pumping system has a pump shaft with a lower ring groove and an upper ring groove. The pump also includes a lower adapter and an upper adapter. The lower adapter has a pair of lower ring halves configured to fit within the lower ring groove and the upper adapter has a pair of upper ring halves configured to fit within the upper ring groove. The pump further includes a plurality of stages that each have a stationary diffuser and a rotating impeller. The rotating impellers are connected to the shaft with a keyed connection that permits the impeller to axially travel along the shaft. Also disclosed is a method for converting a compression shaft to a floater shaft that includes the steps of placing an upper adapter into the upper ring groove, placing one or more impellers on the shaft, placing one or more standard spacers on the shaft and placing a lower adapter into the lower ring groove.
A volumetric compensator assembly for use in the seal section of a pumping system includes an envelope bladder that in turn includes a flexible top sheet and a bottom sheet connected to the top sheet along a pair of side seams and an end seam. The top sheet and bottom sheet together define a bladder interior that has a variable capacity. The volumetric compensator assembly also has a bladder support tube and the envelope bladder is coiled around the bag support tube.
An electric submersible pumping system for use in pumping fluids from a wellbore includes a motor, a pump driven by the motor, and a fluid expansion module connected to the motor. The fluid expansion module includes a piston seal housing and a piston assembly contained within the piston seal housing. The piston assembly includes a piston body having an exterior surface, a plurality of seals connected to the exterior surface of the piston body and a pressure equalization system. The pressure equalization system reduces a pressure differential between fluid in an annular space between the plurality of seals and fluid surrounding the first piston assembly.
F04B 9/133 - Piston machines or pumps characterised by the driving or driven means to or from their working members the means being fluid the fluid being elastic, e.g. steam or air having plural pumping chambers with two mechanically connected pumping members reciprocating movement of the pumping members being obtained by a double-acting elastic-fluid motor
F04B 47/04 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps the driving mechanisms being situated at ground level the driving means incorporating fluid means
A passive multiphase separator is configured to separate gas from a two-phase fluid in a wellbore. The passive multiphase separator includes an intake tube that has an intake end, a discharge end and an interior section between the intake end and the discharge end. The interior section includes a rifled interior surface that induces rotation in fluids passing through the interior section. The passive multiphase separator further includes a head assembly connected to the discharge end of the intake tube. The head assembly includes a crossover tube extending into the interior section, one or more gas vents extending from an interior of the crossover tube to an exterior of the head assembly and a liquid discharge. The passive multiphase separator can be deployed in a variety of hydrocarbon recovery systems.
A magnetic thrust bearing is designed for use in a pumping system that includes a pump driven by a motor through a shaft. The magnetic thrust bearing includes one or more platters that remain stationary with respect to the shaft and one or more thrust discs connected to the shaft and interleaved with the one or more platters. Each of the one or more platters includes a plurality of platter magnets and each of the one or more thrust discs includes a plurality of thrust disc magnets. The magnets on the platters and thrust discs are configured to produce repulsive magnetic forces as the thrust discs approach the platters.
A magnetic thrust bearing is designed for use in a pumping system that includes a pump driven by a motor through a shaft. The magnetic thrust bearing includes one or more platters that remain stationary with respect to the shaft and one or more thrust discs connected to the shaft and interleaved with the one or more platters. Each of the one or more platters includes a plurality of platter magnets and each of the one or more thrust discs includes a plurality of thrust disc magnets. The magnets on the platters and thrust discs are configured to produce repulsive magnetic forces as the thrust discs approach the platters.
According to one embodiment, there is provided herein a method for producing a well lifecycle lift plan that includes considerations of multiple types of lift, multiple lift configurations associated with each lift type, and can be used to provide a prediction of when or if it would be desirable to change the lift plan at some time in the future. Another embodiment utilizes a heuristic database with rules that might be used to limit the solution space in some instances by restricting the solution to feasible configurations. A further embodiment teaches how multiple individual well optimization results might be combined with a reservoir model to obtain an optimized lift schedule for an entire field.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
G05B 13/04 - Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric involving the use of models or simulators
12.
SYSTEM AND METHOD FOR WELL LIFECYCLE PLANNING VISUALIZATION
According to one embodiment, there is provided herein a system and method for producing a well lifecycle lift plan that includes considerations of multiple types of lift, multiple lift configurations associated with each lift type, and can be used to provide a prediction of when or if it would be desirable to change the lift plan at some time in the future. Another embodiment utilizes a heuristic database with rules that might be used to limit the solution space in some instances by restricting the solution to feasible configurations. A further embodiment teaches how multiple individual well optimization results might be combined with a reservoir model to obtain an optimized lift schedule for an entire field.
G06Q 10/0637 - Strategic management or analysis, e.g. setting a goal or target of an organisation; Planning actions based on goals; Analysis or evaluation of effectiveness of goals
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
13.
SYSTEM AND METHOD FOR WELL LIFECYCLE PLANNING VISUALIZATION
According to one embodiment, there is provided herein a system and method for producing a well lifecycle lift plan that includes considerations of multiple types of lift, multiple lift configurations associated with each lift type, and can be used to provide a prediction of when or if it would be desirable to change the lift plan at some time in the future. Another embodiment utilizes a heuristic database with rules that might be used to limit the solution space in some instances by restricting the solution to feasible configurations. A further embodiment teaches how multiple individual well optimization results might be combined with a reservoir model to obtain an optimized lift schedule for an entire field.
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
A pumping system configured to be deployed in a wellbore includes a motor that is filled with a motor lubricant oil, a production pump driven by the motor, a heat exchanger and an internal oil circulation system contained within the pumping system. The internal oil circulation system circulates the motor lubricant oil between the motor and the heat exchanger.
A pumping system deployable in a wellbore includes a primary driven component, a secondary driven component and a motor. The motor is filled with a motor lubricant and includes a stator, a primary rotor assembly configured for rotation within the stator and a primary shaft connected to the primary rotor assembly and to the primary driven component. The motor further includes an internal magnetic coupling assembly inside the stator. The internal magnetic coupling assembly includes a secondary rotor assembly and a secondary shaft. The secondary rotor assembly and the secondary shaft are isolated from the motor fluid.
A submersible pumping system (100) includes an electric motor (110) and a pump (108) driven by the electric motor. The pump (108) includes a rotatable shaft (122) driven by the motor, one or more piston assemblies (132) configured for linear reciprocating motion and a mechanism for converting the rotational movement of the shaft to linear reciprocating movement in the piston assemblies. In one aspect, the mechanism for converting the rotational movement of the shaft includes a tilt disc assembly (134). In another aspect, the mechanism for converting the rotational movement of the shaft includes a camshaft assembly.
F04B 47/06 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
F04B 15/02 - Pumps adapted to handle specific fluids, e.g. by selection of specific materials for pumps or pump parts the fluids being viscous or non-homogeneous
F04B 17/03 - Pumps characterised by combination with, or adaptation to, specific driving engines or motors driven by electric motors
F04B 1/14 - Multi-cylinder machines or pumps characterised by number or arrangement of cylinders having cylinder axes coaxial with, or parallel or inclined to, main shaft axis having stationary cylinders
F04B 1/16 - Multi-cylinder machines or pumps characterised by number or arrangement of cylinders having cylinder axes coaxial with, or parallel or inclined to, main shaft axis having stationary cylinders having two or more sets of cylinders or pistons
F04B 1/053 - Multi-cylinder machines or pumps characterised by number or arrangement of cylinders having cylinders in star- or fan-arrangement with actuating or actuated elements at the inner ends of the cylinders
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
17.
NON-WELDED SUCTION CHAMBER FOR SURFACE PUMPING SYSTEM
A suction chamber for use in a surface pumping system includes a central housing that is substantially cylindrical and has a motor end and a pump end opposite the motor end. The suction chamber includes a motor-end plate bolted to motor end of the central housing and a pump-end plate bolted to the pump end of the central housing. The suction chamber also includes an inlet branch connected to the central housing. A method for assembling a non-welded suction chamber is also disclosed.
F04B 47/02 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps the driving mechanisms being situated at ground level
F04B 53/14 - Pistons, piston-rods or piston-rod connections
A pumping system deployable in a wellbore includes a primary driven component, a secondary driven component and a motor. The motor is filled with a motor lubricant and includes a stator, a primary rotor assembly configured for rotation within the stator and a primary shaft connected to the primary rotor assembly and to the primary driven component. The motor further includes an internal magnetic coupling assembly inside the stator. The internal magnetic coupling assembly includes a secondary rotor assembly and a secondary shaft. The secondary rotor assembly and the secondary shaft are isolated from the motor fluid.
A submersible pumping system has an electric motor (108), a rotary hydraulic pump (106) driven by the electric motor (108), and a linear hydraulic pump (110) that is configured to move a production fluid. The rotary hydraulic pump produces a pressurized working fluid that drives the linear hydraulic pump. In another aspect, a method is disclosed for controlling the temperature of an electric motor within a submersible pumping system disposed in a wellbore. The method includes the steps of circulating motor lubricant through a hydraulically driven production pump to reduce the temperature of the motor lubricant.
F04B 47/06 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
20.
STEP-UP POWER TRANSFORMER WITH INTEGRAL SINE-WAVE FILTER FOR PWM INVERTERS
A pumping system includes an electric motor, a power supply, a variable speed drive connected to the power supply, a transformer connected to the variable speed drive and a power cable connected between the transformer and the electric motor. The transformer includes a sine-wave filter that has inductors contained within an oil-filled central tank.
H01F 27/34 - Special means for preventing or reducing unwanted electric or magnetic effects, e.g. no-load losses, reactive currents, harmonics, oscillations, leakage fields
H01F 27/40 - Structural association with built-in electric component, e.g. fuse
H01F 27/42 - Circuits specially adapted for the purpose of modifying, or compensating for, electric characteristics of transformers, reactors or choke coils
21.
MODULAR SEAL SECTION WITH EXTERNAL PORTS TO CONFIGURE CHAMBERS IN SERIES OR PARALLEL CONFIGURATION
A modular seal section for use within a downhole pumping system includes an upper fluid compensation section, a lower fluid compensation section and a guide body connected between the upper fluid compensation section and lower fluid compensation section. The guide body includes a configuration selection mechanism that can be externally manipulated to selectively place the upper fluid compensation section in either a series or parallel configuration with the lower fluid compensation section.
A horizontal pumping system for pumping fluids into downstream piping includes a motor and a pump driven by the motor. The pump includes a discharge assembly for use in connecting a pump within a horizontal pumping system to downstream piping. The discharge assembly preferably includes a discharge head and a stub end configured for sliding engagement with the discharge head. The stub end is captured within the discharge head in a hydraulically balanced condition and the discharge assembly further includes a hydraulic balance chamber and a runner plate within the hydraulic balance chamber. The runner plate is secured to the stub end.
A virtual sensor system includes one or more electric submersible pumping systems deployed in a reservoir and a computer system that receives data from the one or more electric submersible pumping systems. Field data is provided to computerized statistical models for predicting whether individual electric submersible pumping systems and the reservoir have undergone changes in condition. The statistical models are established with reference data obtained by running electric submersible pumping systems of known working condition in test wells under a variety of controlled conditions.
A pumping system for use in a subterranean wellbore below a surface includes a motor assembly, a pump driven by the motor assembly, and one or more sensors configured to measure an operating parameter within the pumping system and output a signal representative of the measured parameter. The pumping system further includes a wireless telemetry system that is configured to transmit data representative of the measured parameter from the pumping system to the surface. The one or more sensors may include acoustically active sensors that operate according to surface acoustic wave principles.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
F04D 13/10 - Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
25.
METHOD OF HEATING DOWNHOLE ESP MOTOR WHEN NOT IN OPERATION
A method for heating an electric motor within a submersible pumping system that includes the step of applying alternating current (AC) or direct current (DC) power to the motor. The method may also include the additional steps of establishing a desired motor temperature range, measuring the temperature of the motor, comparing the temperature of the motor to the desired motor temperature range, and applying DC power to the motor to raise the temperature of the motor.
An electric submersible pumping system for use in pumping fluids from a wellbore includes a motor that is filled with a motor lubricant, a pump driven by the motor, a thrust chamber connected between the motor and the pump, and a seal section. The thrust chamber is filled with thrust chamber lubricant and the motor and seal section are filled with motor lubricant. To prevent the mixing of the thrust chamber lubricant with the motor lubricant, the thrust chamber is in fluid isolation from the motor and the seal section. The electric submersible pumping system may include an upper seal section, a lower seal section or both upper and lower seal sections.
A seal section for use in a downhole submersible pumping system includes one or more fluid separation mechanisms, a shaft, a mechanical seal chamber and a mechanical seal inside the mechanical seal chamber. The seal section further comprises a mechanical seal protector around the mechanical seal. The mechanical seal protector includes a cap that surrounds a portion of the mechanical seal and a filter screen. The cap may also include one or more expulsion ports extending through the cap. The cap may be stationary or connected to the shaft and configured for rotation.
A shaft coupling is useful for connecting a distal end of a first shaft with a proximal end of a second shaft. The shaft coupling includes a body, a first receiving chamber within the body and a second receiving chamber within the body. The first receiving chamber receives the distal portion of the first shaft and the second receiving chamber receives the proximal portion of the second shaft. A pin maintains the axial positioning between the body and the distal portion of the first shaft. An axially adjustable connection is used between the second receiving chamber and the proximal portion of the second shaft.
A thrust control assembly for use in a horizontal pumping system includes a thrust bearing chamber that is filled with a fluid lubricant, a thrust bearing assembly contained within the thrust bearing chamber, a first radial bearing chamber, a first radial bearing assembly contained within the first radial bearing chamber and a first metering assembly. The first metering assembly controls the flow of lubricant from the thrust bearing chamber to the first radial bearing chamber. The first metering assembly may include an orifice plate.
A shaft coupling for connecting a first shaft to a second shaft includes a first hub that has a shaft sleeve that fits over a portion of the first shaft. The first hub also includes a connection flange connected to the shaft sleeve. The shaft coupling further includes a compression fitting that fits over the shaft sleeve to apply a compressive force to the shaft sleeve and first shaft. The shaft coupling further includes a second hub that is connected to the second shaft and to the first hub.
A thrust bearing assembly configured to reduce the axial displacement of a shaft includes a stationary thrust bearing, a thrust runner adjacent to the thrust bearing and a taper sleeve driver. The thrust runner includes a central passage. The taper sleeve driver includes an interior surface in contact with the shaft and an exterior surface in contact with the central passage of the thrust runner. The taper sleeve driver has a tapered exterior surface that applies a radially directed clamping force against the thrust runner as the taper sleeve driver is engaged within the central passage.
A frame for supporting a horizontal pumping system includes a base assembly and a motor support assembly connected to the base assembly. The motor support assembly includes an upper support plate having a top and a bottom, a first lower support plate connected to the upper support plate, and a second lower support plate connected to the upper support plate. The first and second lower support plates are connected to the upper plate with bolted and welded connections.
Cable protector including a first clamp section (122) and a second clamp section (124). The second clamp section includes a lead cable recess (148) that extends in a longitudinal direction along the exterior of the second clamp section and a band recess that extends in a circumferential direction along the exterior of the second clamp section. A tie or band resides in the band recess (154) and extends around the circumference of the cable protector to secure the motor lead cable within the lead cable recess. Also pumping system comprising the cable protector.
A suspension assembly for supporting a shock-sensitive component includes an outer housing and a plurality of radial canted coil springs that surround and support the shock- sensitive component. Each of the plurality of radial canted coil springs is preferably a toroid. The exterior of each of the plurality of radial canted coil springs is in contact with the outer housing and the interior of each of the plurality of canted radial canted coil springs is in contact with the exterior of the shock-sensitive component. The radial canted coil springs dampen mechanical shock and vibration applied in a lateral direction. The suspension assembly optionally includes an axial canted coil spring that dampens mechanical shock in the axial direction. The outer housing may include grooves that locate the radial canted coil springs within the suspension assembly.
B60G 15/06 - Resilient suspensions characterised by arrangement, location, or type of combined spring and vibration- damper, e.g. telescopic type having mechanical spring and fluid damper
A seal section for use in a downhole submersible pumping system (100) includes redundant fluid separation mechanisms. The fluid separation mechanisms are bag seal assemblies (122, 124), labyrinth seals, pistons and bellows. The seal section further includes a shaft, one or more shaft seals and a bag support tube. An annulus between the shaft and the shaft support tube provides a fluid flow path from a motor to the fluid separation mechanisms.
A multistage centrifugal pump includes an upstream housing and a downstream housing. The upstream housing and the downstream housing each have a first end, a second end and a plurality of turbomachinery stages. Each of the plurality of turbomachinery stages includes a diffuser and an impeller. A compression bulkhead is connected between the second end of the upstream housing and the first end of the downstream housing. The compression bulkhead applies a compressive force to the diffusers within the upstream housing.
A pumping system is configured for deployment in a non- vertical wellbore. The pumping system includes a plurality of articulating components. Each of the plurality of articulating components is connected to an adjacent other of the plurality of articulating components with an articulating joint. In preferred embodiments, the articulating joint is a ball- and-socket mechanism. The articulating components include a body having a first end and a second end, a ball connected to the first end the body and a socket connected to the second end of the body. A locking collar is connected to the socket to secure the ball portion of an adjacent articulating component to the socket.
An electric submersible pumping system includes a motor filled with motor lubricant, a pump driven by the motor, and a fluid expansion chamber connected to the motor. The fluid expansion chamber includes a seal bag filled with a seal bag lubricant and a bellows contained within the seal bag. The bellows includes an interior in fluid communication with the motor and an exterior in fluid communication with the seal bag lubricant.
An electric submersible pumping system includes a motor filled with motor lubricant, a pump driven by the motor, and a fluid expansion chamber connected to the motor. The fluid expansion chamber includes a seal bag filled with a seal bag lubricant and a bellows contained within the seal bag. The bellows includes an interior in fluid communication with the motor and an exterior in fluid communication with the seal bag lubricant.
An electric submersible pumping system includes a motor, a production pump driven by the motor, a heat exchanger and an oil circulation pump connected to the motor. The production pump moves fluids from the wellbore through the heat exchanger. The oil circulation pump circulates oil between the motor and the heat exchanger to moderate the operating temperature of the motor. Heat absorbed by the oil moving through the motor is transferred to the produced fluid moving through the heat exchanger.
A seal section for use in a downhole submersible pumping system includes one or more fluid separation mechanisms, a shaft and one or more primary mechanical seals. Each of the one or more primary mechanical seals is disposed along the shaft. The seal section also includes one or more redundant shaft seals that each substantially surrounds a corresponding one of the one or more primary mechanical seals. In another aspect, a seal section for use in a pumping system includes one or more fluid separation mechanisms, a shaft, a primary mechanical seal and a redundant shaft seal. The redundant shaft seal substantially surrounds the primary mechanical seal. The seal section further includes an internal seal chamber defined by the annular space between the primary mechanical seal and the redundant shaft seal.
A fluid processor for use in a downhole pumping operation includes a fluid processing stage (126), a nozzle stage (128) and a gas compressor stage (130). The nozzle chamber is configured as a convergent-divergent nozzle and the variable metering member is configured for axial displacement within the convergent section to adjust the open cross-sectional area of the nozzle. A method for producing gas containing liquid with a pumping system includes the steps of measuring the gas-to-liquid ratio of the fluid and operating a motor of the pumping system at low speed when the gas-to-liquid ratio is low and at high speed when the gas-to-liquid ratio is high. The nozzle stage meters the flow of fluid into the gas compressor and reduces the size of liquid droplets entrained in the fluid stream.
A multistage centrifugal pump includes a housing, a rotatable shaft and first and second turbomachinery stages. The first turbomachinery stage includes a first diffuser connected to the housing, a first impeller connected to the rotatable shaft. The second turbomachinery stage includes a second diffuser connected to the housing and a second impeller connected to the rotatable shaft. The multistage centrifugal pump further includes an integral axial load and bearing system that includes at least one diffuser bushing and at least one impeller bearing. The integral axial load and bearing system permits the independent axial movement of the first and second impellers. The integral axial load and bearing system also provides an opposite force to up-thrust and down-thrust produced by the first and second turbomachinery stages.
An electric submersible pumping system includes an electric motor and a motor lead cable. The motor lead cable includes a plurality of leads that each includes a conductor, an insulator and a sealing sleeve around the insulator. The sealing sleeve is constructed of metal in preferred embodiments. The electric submersible pumping system further includes a pothead connector attached to the electric motor and the motor lead cable. The pothead connector includes a sealing mechanism around the metal sleeve of each of the plurality of leads.
A multistage centrifugal pump includes a housing, a rotatable shaft and first and second turbomachinery stages. The first turbomachinery stage includes a first diffuser connected to the housing, a first impeller connected to the rotatable shaft. The second turbomachinery stage includes a second diffuser connected to the housing and a second impeller connected to the rotatable shaft. The multistage centrifugal pump further includes an integral axial load and bearing system that includes at least one diffuser bushing and at least one impeller bearing. The integral axial load and bearing system permits the independent axial movement of the first and second impellers. The integral axial load and bearing system also provides an opposite force to up-thrust and down-thrust produced by the first and second turbomachinery stages.
A method for applying a metalized polymer film (140) to a seal bag (118) for use in a downhole submersible pumping system includes the steps of applying a metal layer (142) to a polymer layer (144), applying an adhesive layer (146) to the polymer layer (144), and rolling the adhesive layer (146) onto a substrate of the seal bag (118). The method may also include the steps of rotating a first roller, which is located above the polymer layer of the metalized polymer film (140), and rotating a second roller, which is located on an interior surface of the substrate of the seal bag, in the opposite direction of the first roller. Also disclosed is a downhole pumping system that incorporates a seal bag (118) manufactured from these techniques.
B29C 63/14 - Lining or sheathing, i.e. applying preformed layers or sheathings of plastics; Apparatus therefor using sheet or web-like material by folding, winding, bending or the like by winding spirally around tubular articles
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F04B 47/06 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
F04D 13/10 - Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
F04C 13/00 - Adaptations of machines or pumps for special use, e.g. for extremely high pressures
A port for use in introducing a fluid into an internal fluid chamber includes a plug bore, a valve disposed in the plug bore and a plug. The plug includes one or more seal grooves and a ring seal in each of the one or more seal grooves. The ring seal creates a seal between the plug and the plug bore. The port further includes a positive stop barrier that prevents the plug from being removed from the plug bore.
A port for use in introducing a fluid into an internal fluid chamber includes a plug bore, a valve disposed in the plug bore and a plug. The plug includes one or more seal grooves and a ring seal in each of the one or more seal grooves. The ring seal creates a seal between the plug and the plug bore. The port further includes a positive stop barrier that prevents the plug from being removed from the plug bore.
An electric submersible pumping system is configured to pump fluids from a wellbore. The electric submersible pumping system includes a motor filled with dielectric motor lubricant and a pump driven by the motor. The electric submersible pumping system further includes an upper seal section connected to the motor and filled with seal section oil. The electric submersible pumping system also includes a lower seal section connected to the motor. In preferred embodiments, the lower seal section includes an expansible bladder that isolates the dielectric motor lubricant from wellbore fluids. The upper seal section is in fluid isolation from the motor. The lower seal section is in fluid communication with the motor.
A distributed artificial lift system is configured for use in a wellbore (102) that includes a vertical section (102a) and at least one lateral section (102b) connected to the vertical section. The distributed artificial lift system includes a first remote assembly (106) positioned within the first lateral section. The first remote assembly includes an equipment deployment vehicle (118) and cargo (120) selected from the group consisting of electric remote pumping units, tubing, tubing connectors, tubing adaptors, sensor packages, gas separators, perforating tools, injection pumps and other downhole components. The first remote assembly is optionally self-propelled and remotely- controlled.
A self-propelled, remotely-controlled equipment deployment vehicle is configured to deliver equipment to a desired location within the horizontal portion of a deviated wellbore. The deployment vehicle includes a cargo frame, an electric motor and an active mobility assembly. The active mobility assembly is connected to the cargo frame and powered by the electric motor. The cargo frame can be configured to transport, offload and accurately position the selected cargo. Alternatively, the equipment deployment vehicle can be configured with a passive mobility assembly that allows the equipment deployment vehicle to be pushed or pulled along the horizontal section of the wellbore without power.
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
E21B 27/00 - Containers for collecting or depositing substances in boreholes or wells, e.g. bailers for collecting mud or sand; Drill bits with means for collecting substances, e.g. valve drill bits
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
52.
SPRING-ENERGIZED SEAL FOR HIGH TEMPERATURE SEALING OF POWER CABLE TO CONNECTOR
A high temperature connector for use in connecting a power cable to an electric motor includes an outer housing, and inner housing inside the outer housing and a cable conductor disposed through the inner housing. To maintain a seal around the cable conductor during thermal expansion and contraction, the connector includes at least one spring-energized seal disposed around the cable conductor. The spring-energized seal permits the expansion and contraction of the cable conductor without deforming the cable conductor or the inner housing.
H01R 4/00 - Electrically-conductive connections between two or more conductive members in direct contact, i.e. touching one another; Means for effecting or maintaining such contact; Electrically-conductive connections having two or more spaced connecting locations for conductors and using contact members penetrating insulation
An electric submersible pumping system (100) includes a motor (110) that is filled with motor lubricant fluid and a pump (108) driven by the motor. The electric submersible pumping system further includes a fluid expansion module (114) connected to the motor (110) that is designed to accommodate the expansion and contraction of the motor lubricant fluid in the motor. The fluid expansion module (114) preferably includes a piston seal housing (130) in fluid communication with the motor (110) and a bag seal housing (132) in fluid communication with the piston seal housing (130). The fluid expansion module further includes at least one axially movable barrier (134a, 134b) in the piston seal housing (130) and at least one expansible barrier (136) in the bag seal housing (132). The axially movable barrier (134a, 134b) and the expansible barrier (136) cooperate to permit the expansion of the motor lubricant fluid without contaminating the motor lubricant fluid with fluids or and solids from the wellbore.
F04D 13/06 - Units comprising pumps and their driving means the pump being electrically driven
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
F04D 13/10 - Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
H02K 5/12 - Casings or enclosures characterised by the shape, form or construction thereof specially adapted for operating in liquid or gas
F04B 35/04 - Piston pumps specially adapted for elastic fluids and characterised by the driving means to their working members, or by combination with, or adaptation to, specific driving engines or motors, not otherwise provided for the means being electric
A pump assembly (108) for use within a high pressure pumping system (100) includes housing (124), a head (128) and a base (126). The housing contains at least one centrifugal pump stage (130). The head (128) and base (126) are attached to the housing (124) with corresponding internal threaded connections (140,144). The head (128) and base (126) are further retained to the housing (124) with corresponding external flanged connections (138,142). The external flanged connections (138,142) provide redundant connections that reduce the risk of separation between the housing (124) and the head (128) and base (126).
A vent box for venting gases present on a power cable used to provide power to an electric submersible pumping system includes a front, a back, a plurality of sides, a top and a bottom. The vent box includes one or more upper vents positioned along an upper edge of at least one of the front, the back or the plurality of sides. The vent box further includes one or more lower vents that extend through the bottom. The top includes a weather cap that extends downward from the top to partially conceal the one or more upper vents.
A pumping system frame assembly (100) for use in supporting a horizontal pumping system (200) on a platform includes a central body assembly (102), a motor plate (104) connected to the central body assembly (102) and a plurality of platform support assemblies (110) connected to the central support member. The central body assembly (102) includes a central support member that has an upper face (114) and a pair of side rails (116) connected to the upper face (114). In particularly preferred embodiments, each of the pair of side rails (116) extends downward from the upper face (114) at approximately a 45 degree angle.
A system and process for optimizing the performance and evaluating the risks of pumping systems includes the steps of measuring the operation and condition of components within a discrete electric submersible pumping system, accumulating these measurements across a field of electric submersible pumping systems, performing statistical analysis on the accumulated measurements and producing one or more selected outputs from the group statistical analysis. In the preferred embodiments, the statistical analysis and data processing occurs at both the individual pumping system and at one or more centralized locations.
A suction chamber (104) for use in a horizontal fluid pumping system (100) is supported by a fixed vertical bracket (118), which is attached to a platform (112). The suction chamber (104) is positioned between a motor (102) and a pump (106) in the horizontal pumping system. The pumping system (100) may also include a thrust bearing chamber (120) positioned between the motor (102) and the suction chamber (116) and a bearing chamber adapter (122) positioned between the thrust bearing chamber (120) and the suction chamber (116). The suction chamber (116) has a suction chamber pump end and a suction chamber motor end and enables both motor-end seal removal and pump-end seal removal. In both motor end seal removal and pump end seal removal, the suction chamber (116) of the invention remains connected to the vertical bracket (118). The pumping system (100) may also include an integrated lifting device (232) connected to the vertical bracket (118) to lift the thrust bearing assembly.
An electric submersible pumping system (100) has an electric motor (110), a pump assembly (108) driven by the electric motor and a sensor module (114). The sensor module preferably includes a detachable sensor array that can be selectively released from the sensor module. In preferred embodiments, the detachable sensor array includes a self-propelled sensor array vehicle (136) that has a drive motor (138), a drive mechanism (142) driven by the drive motor and a sensor array (144). The detachable sensor array provides a wellbore condition signal that can be used to automatically adjust the performance of the electric submersible pumping system.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
An electric submersible pumping system (100) has an electric motor (110), a pump assembly (108) driven by the electric motor and a sensor module (114). The sensor module preferably includes a detachable sensor array that can be selectively released from the sensor module. In preferred embodiments, the detachable sensor array includes a self-propelled sensor array vehicle (136) that has a drive motor (138), a drive mechanism (142) driven by the drive motor and a sensor array (144). The detachable sensor array provides a wellbore condition signal that can be used to automatically adjust the performance of the electric submersible pumping system.
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
F04D 13/10 - Units comprising pumps and their driving means the pump being electrically driven for submerged use adapted for use in mining bore holes
62.
HIGH TEMPERATURE DOWNHOLE MOTORS WITH ADVANCED POLYIMIDE INSULATION MATERIALS
An electric motor assembly configured for use in a downhole pumping system includes a number of electrically conductive components that are insulated from fluids, mechanical abrasion, electrical current and electrical grounds using an advanced polyimide film. Preferred polyimide films include poly(4,4'-oxydiphenylene-pyromellitimide) and biphenyl-tetracarboxylic acid dianhydride (BPDA) type polyimide films. Magnet wire, stator laminates, stator coil end turns, motor leads and power cables can all be insulated with the selected polyimide film.
H01B 3/30 - Insulators or insulating bodies characterised by the insulating materials; Selection of materials for their insulating or dielectric properties mainly consisting of organic substances waxes
H01B 3/42 - Insulators or insulating bodies characterised by the insulating materials; Selection of materials for their insulating or dielectric properties mainly consisting of organic substances waxes polyacetals
H01B 3/44 - Insulators or insulating bodies characterised by the insulating materials; Selection of materials for their insulating or dielectric properties mainly consisting of organic substances waxes acrylic resins
09 - Scientific and electric apparatus and instruments
42 - Scientific, technological and industrial services, research and design
Goods & Services
(1) Software for remote monitoring, sensing, and diagnostics of equipment used in the drilling, pumping, refining, and transporting of oil; software used for remote monitoring, sensing, and diagnostics of equipment used in the artificial lift of oil. (1) Providing on-line non-downloadable software for remote monitoring, sensing, and diagnostics of equipment used in the drilling, pumping, refining, and transporting of oil; providing on-line non-downloadable software used for remote monitoring, sensing, and diagnostics of equipment in the artificial lift of oil.
A gas separator is configured to separate gas from a two-phase fluid. The gas separator includes a rotatable shaft and one or more separation stages. At least one of the one or more separation stages includes a rotor connected to the rotatable shaft and a channeled compression tube, wherein the channeled compression tube includes a compression tube hub and a plurality of channels. The channels are configured to isolate abrasive solid particles from the rotary components within the gas separator. The gas separator may optionally include a streamer upstream from the separation stage that reduces rotational currents upstream from the rotor.
An independent power system provides electrical power to an electric submersible pumping system positioned in a well that produces petroleum products. The independent power system includes a generator and an engine connected to the generator. The engine is preferably provided with combustible gases from the petroleum products of the well. The independent power system further includes an integrated control system that is connected to the electric submersible pumping system and the generator. The independent power system is configured to balance the loads created by the electric submersible pumping system with the output from the electrical generator.
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 drive line to a production pump. The production pump pressurizes production fluids, which are carried under pressure to the surface.
A downhole submersible pumping system includes an adapter for use in connecting a first component to a second component within the downhole pumping system. The adapter preferably includes an upstream section configured for connection to the first component and a downstream section configured for connection to the second component. The adapter further includes an articulating joint that permits the angular movement of the first component with respect to the second component.
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
F04C 13/00 - Adaptations of machines or pumps for special use, e.g. for extremely high pressures
F04C 15/00 - Component parts, details or accessories of machines, pumps or pumping installations, not provided for in groups
A downhole submersible pumping system includes an adapter for use in connecting a first component to a second component within the downhole pumping system. The adapter preferably includes an upstream section configured for connection to the first component and a downstream section configured for connection to the second component. The adapter further includes an articulating joint that permits the angular movement of the first component with respect to the second component.
F04C 13/00 - Adaptations of machines or pumps for special use, e.g. for extremely high pressures
F04C 15/00 - Component parts, details or accessories of machines, pumps or pumping installations, not provided for in groups
F04C 2/107 - Rotary-piston machines or pumps of intermeshing-engagement type, i.e. with engagement of co-operating members similar to that of toothed gearing of internal-axis type with the outer member having more teeth or tooth-equivalents, e.g. rollers, than the inner member with helical teeth
A centrifugal pump (108) has a gas accumulation reduction system to reduce the risk of gas locking caused by the accumulation of gas at the inlet of the impeller. The gas accumulation reduction system includes: (i) one or more diffuser ports (164) extending through the hub (140) of a diffuser; and (ii) one or more recirculation passages (158) extending through the hub (148) of an impeller (122E). The recirculation passages are in fluid communication with the one or more diffuser ports to permit the recirculation of a portion of pumped fluid through the stage. Additionally, a centrifugal pump that includes at least one turbomachinery stage (120) is disclosed. The stage includes a rotatable impeller (124) that has an impeller hub with a centrally disposed eye and a plurality of impeller vanes. The impeller is variously configured to encourage mixing of two-phase fluids at the eye of the impeller hub.
F04D 7/04 - Pumps adapted for handling specific fluids, e.g. by selection of specific materials for pumps or pump parts of centrifugal type the fluids being viscous or non-homogeneous
F04D 13/08 - Units comprising pumps and their driving means the pump being electrically driven for submerged use
F04D 29/22 - Rotors specially for centrifugal pumps
A centrifugal pump (108) has a gas accumulation reduction system to reduce the risk of gas locking caused by the accumulation of gas at the inlet of the impeller. The gas accumulation reduction system includes: (i) one or more diffuser ports (164) extending through the hub (140) of a diffuser; and (ii) one or more recirculation passages (158) extending through the hub (148) of an impeller (122E). The recirculation passages are in fluid communication with the one or more diffuser ports to permit the recirculation of a portion of pumped fluid through the stage. Additionally, a centrifugal pump that includes at least one turbomachinery stage (120) is disclosed. The stage includes a rotatable impeller (124) that has an impeller hub with a centrally disposed eye and a plurality of impeller vanes. The impeller is variously configured to encourage mixing of two-phase fluids at the eye of the impeller hub.
F04D 7/04 - Pumps adapted for handling specific fluids, e.g. by selection of specific materials for pumps or pump parts of centrifugal type the fluids being viscous or non-homogeneous
F04D 13/08 - Units comprising pumps and their driving means the pump being electrically driven for submerged use
F04D 29/22 - Rotors specially for centrifugal pumps
71.
ENHANCED DEVICE FOR DETERMINING THE LOCATION OF INDUCED STRESS IN STUCK BOREHOLE TUBULARS
A method for identifying the location of a binding zone between a stuck tubular and a borehole includes the steps of passing a demagnetizing stress sensor through the tubular on a baseline magnetization pass to magnetize the tubular. Next, the demagnetizing stress sensor measures a baseline magnetization of the tubular. Once the baseline magnetization has been established, the method continues by applying a stress to the tubular and passing the demagnetizing stress sensor through the tubular on a scanning pass while the tubular is stressed. The demagnetizing stress sensor then measures a stress-induced magnetization of the tubular. The method concludes by comparing the baseline magnetization of the tubular against the stress-induced magnetization of the tubular. Notably, in preferred embodiments, the method includes the magnetization of the tubular in a substantially radial direction and the stresses are applied in vectors perpendicular to the radial magnetization of the tubular.
E21B 47/092 - Locating or determining the position of objects in boreholes or wells; Identifying the free or blocked portions of pipes by detecting magnetic anomalies
72.
HIGH TEMPERATURE DOWNHOLE MOTORS WITH ADVANCED POLYIMIDE INSULATION MATERIALS
An electric motor assembly configured for use in a downhole pumping system includes a number of electrically conductive components that are insulated from fluids, mechanical abrasion, electrical current and electrical grounds using an advanced polyimide film. Preferred polyimide films include poly(4,4'-oxydiphenylene-pyromellitimide) and biphenyl-tetracarboxylic acid dianhydride (BPDA) type polyimide films. Magnet wire, stator laminates, stator coil end turns, motor leads and power cables can all be insulated with the selected polyimide film.
F04D 13/08 - Units comprising pumps and their driving means the pump being electrically driven for submerged use
H01B 3/30 - Insulators or insulating bodies characterised by the insulating materials; Selection of materials for their insulating or dielectric properties mainly consisting of organic substances waxes
H02K 1/04 - DYNAMO-ELECTRIC MACHINES - Details of the magnetic circuit characterised by the material used for insulating the magnetic circuit or parts thereof
H02K 3/30 - Windings characterised by the insulating material
73.
MAGNET WIRE WITH SHIELDED HIGH TEMPERATURE PERFLUOROPOLYMER INSULATION
An electrical submersible pumping system includes a pump assembly and a motor assembly. The motor assembly includes a plurality of stator coils and each of the plurality of stator coils comprises magnet wire. The magnet wire includes an inner insulation layer and an outer protective layer. The inner insulation layer is preferably constructed from a high-temperature, epitaxial co-crystallized perfluoropolymer that exhibits favorable resistance to elevated temperatures. The outer protective layer shields the inner insulation layer from mechanical abrasion and contaminants.
H01B 3/30 - Insulators or insulating bodies characterised by the insulating materials; Selection of materials for their insulating or dielectric properties mainly consisting of organic substances waxes
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
F04D 13/08 - Units comprising pumps and their driving means the pump being electrically driven for submerged use
H02K 1/04 - DYNAMO-ELECTRIC MACHINES - Details of the magnetic circuit characterised by the material used for insulating the magnetic circuit or parts thereof
H02K 3/30 - Windings characterised by the insulating material
74.
METALIZED POLYMER COMPONENTS FOR USE IN HIGH TEMPERATURE PUMPING APPLICATIONS
A seal section (112) for use in a downhole submersible pumping system (100) includes a housing (114) and a seal bag (118) located within the housing. The seal bag includes a substrate (130) having a plurality of substrate surfaces (136, 138) and a metal coating layer (140) on at least one of the plurality of substrate surfaces. The substrate can optionally be configured as a cylindrical form that includes an interior surface and an exterior surface. In particularly preferred embodiments, the substrate is seamless and fabricated from an extruded fluoropolymer. The metal coating layer preferably comprises a metal selected from the group consisting of titanium, stainless steel, nickel, chrome, silver and gold. The metalized seal bag exhibits increased durability and decreased permeability to liquids and gases at elevated temperatures.
A mechanical seal (122) has a stationary face (142) and rotating assembly (140) adjacent to the stationary face. The rotating assembly includes an upper bellows ring (146), a lower bellows ring (148) and a runner (172) between the lower bellows ring and the stationary face. A bellows (144) extends between the upper bellows ring and the lower bellows ring. In preferred embodiments, the bellows is constructed from a perfluoroalkoxy polymer and is secured within the upper bellows ring and the lower bellows ring by a selected locking mechanism. The locking mechanism may include the use of crimp rings (156, 158) configured for a press fit engagement within the upper and lower bellows rings. Alternatively, the locking mechanism may employ locking rings (176, 178) configured for threaded engagement with the upper and lower bellows rings.
F16J 15/36 - Sealings between relatively-moving surfaces with slip-ring pressed against a more or less radial face on one member connected by a diaphragm to the other member
A mechanical seal (122) has a stationary face (142) and rotating assembly (140) adjacent to the stationary face. The rotating assembly includes an upper bellows ring (146), a lower bellows ring (148) and a runner (172) between the lower bellows ring and the stationary face. A bellows (144) extends between the upper bellows ring and the lower bellows ring. In preferred embodiments, the bellows is constructed from a perfluoroalkoxy polymer and is secured within the upper bellows ring and the lower bellows ring by a selected locking mechanism. The locking mechanism may include the use of crimp rings (156, 158) configured for a press fit engagement within the upper and lower bellows rings. Alternatively, the locking mechanism may employ locking rings (176, 178) configured for threaded engagement with the upper and lower bellows rings.
F16J 15/36 - Sealings between relatively-moving surfaces with slip-ring pressed against a more or less radial face on one member connected by a diaphragm to the other member
An electric motor assembly configured for use in a downhole pumping system includes a plurality of stator coils. Each of the plurality of stator coils includes magnet wire that has an insulator surrounding a conductor. In preferred embodiments, the insulator is manufactured from a material selected from the group consisting of polyether ketone and polyether ketone ether ketone ketone.
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
H01B 3/42 - Insulators or insulating bodies characterised by the insulating materials; Selection of materials for their insulating or dielectric properties mainly consisting of organic substances waxes polyacetals
F04D 13/08 - Units comprising pumps and their driving means the pump being electrically driven for submerged use
H02K 1/04 - DYNAMO-ELECTRIC MACHINES - Details of the magnetic circuit characterised by the material used for insulating the magnetic circuit or parts thereof
H02K 3/30 - Windings characterised by the insulating material
78.
USE OF PEEK FILM AS A WRAP INSULATION MATERIAL ON MAGNET WIRE
An electrical submersible pumping system includes a pump assembly and a motor assembly. The motor assembly includes a plurality of stator coils and each of the plurality of stator coils comprises magnet wire. The magnet wire has an insulator surrounding a conductor and the insulator is manufactured from a polyether ether ketone film. In another aspect, the preferred embodiments provide a method for manufacturing a motor assembly for use in an electrical submersible pumping system. The method includes steps of preparing magnet wire having an electrical conductor and a polyether ether ketone film insulator.
H01B 3/30 - Insulators or insulating bodies characterised by the insulating materials; Selection of materials for their insulating or dielectric properties mainly consisting of organic substances waxes
H01B 3/42 - Insulators or insulating bodies characterised by the insulating materials; Selection of materials for their insulating or dielectric properties mainly consisting of organic substances waxes polyacetals
F04D 13/08 - Units comprising pumps and their driving means the pump being electrically driven for submerged use
H02K 1/04 - DYNAMO-ELECTRIC MACHINES - Details of the magnetic circuit characterised by the material used for insulating the magnetic circuit or parts thereof
H02K 3/30 - Windings characterised by the insulating material
09 - Scientific and electric apparatus and instruments
42 - Scientific, technological and industrial services, research and design
Goods & Services
Software for remote monitoring, sensing, and diagnostics of equipment used in the drilling, pumping, refining, and transporting of oil; software used for remote monitoring, sensing, and diagnostics of equipment used in the artificial lift of oil Providing on-line non-downloadable software for remote monitoring, sensing, and diagnostics of equipment used in the drilling, pumping, refining, and transporting of oil; Providing on-line non-downloadable software used for remote monitoring, sensing, and diagnostics of equipment in the artificial lift of oil
A motor assembly for use in a downhole submersible pumping system includes an electric motor and a motor protection bag. The motor protection bag surrounds a portion of the exterior surface of the motor to form an impermeable, corrosion-resistant barrier. The motor protection bag comprises a seamless, elongate cylindrical having a substantially constant inner diameter and open ends. The motor protection bag may be constructed from a suitable polymer, such as perfluoroalkoxy (PFA) fluoropolymer. The motor protection bag is held in place along the exterior surface of the motor with a plurality of clamps that prohibit the migration of fluid between the exterior of the motor and the motor protection bag.
H02K 5/10 - Casings or enclosures characterised by the shape, form or construction thereof with arrangements for protection from ingress, e.g. of water or fingers
A seal section for use in a downhole submersible pumping system includes a housing, a bag support tube extending through the housing, a shaft positioned inside the bag support tube and a bag plate connected to the bag support tube. The bag plate preferably includes an end cap secured to the bag support tube and a locking collar threadingly engaged with the end cap. The bag plate is configured to receive the open end of a cylindrical seal bag manufactured from perflouroalkoxy polymer. The end cap includes a tapered head that tapers from a first diameter that is slightly larger than the inner diameter of the seal bag to a second diameter that is slightly smaller than the inner diameter of the seal bag. This mechanism for securing the seal bag obviates the need for o-ring or other mechanical seals between the seal bag and the bag plate.
E21B 33/10 - Sealing or packing boreholes or wells in the borehole
F04B 47/06 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps having motor-pump units situated at great depth
F04B 53/00 - Component parts, details or accessories not provided for in, or of interest apart from, groups or
F04D 13/08 - Units comprising pumps and their driving means the pump being electrically driven for submerged use
F16J 15/46 - Sealings with packing ring expanded or pressed into place by fluid pressure, e.g. inflatable packings
37 - Construction and mining; installation and repair services
42 - Scientific, technological and industrial services, research and design
Goods & Services
MAINTENANCE AND REPAIR OF OIL AND GAS WELL EQUIPMENT MONITORING OIL AND GAS WELL PERFORMANCE FOR OTHERS, NAMELY, MEASURING MONTHLY FLUID LEVELS AND PERFORMING SURFACE CHECKS AND CONTROLS; MONITORING OIL AND GAS WELL PERFORMANCE FOR OTHERS, NAMELY, MAINTAINING CURRENT AND HISTORICAL DATA ON WELLS AND THE SUBMERSIBLE PUMPING SYSTEM EQUIPMENT USED THEREIN; AND OIL WELL TESTING
42 - Scientific, technological and industrial services, research and design
Goods & Services
MONITORING OIL AND GAS WELL PERFORMANCE FOR OTHERS, NAMELY, MAINTAINING CURRENT AND HISTORICAL DATA ON WELLS AND THE SUBMERSIBLE PUMPING SYSTEM EQUIPMENT USED THEREIN
