A method of monitoring the performance of a multi-phase electric motor (13), wherein the electric motor comprises a plurality of stator windings (7, 8, 9) connected in a wye configuration to form a wye point. The method comprises measuring an electrical characteristic of the wye point in a time domain; based upon the measured electrical characteristic of the wye point in the time domain, determining an electrical characteristic of the wye point in the frequency domain; and deriving data indicative of at least one parameter of the performance of the electric motor based upon the determined electrical characteristic of the wye-point in the frequency domain.
The present disclosure is for a tool for measurement of phases in fluid in downhole applications. The tool includes a light coupler for providing a first light and for detecting a second light. The first light is provided to an optical interface and the second light is received from the optical interface. The optical interface is between the tool and the fluid. An optical path is provided that is integral or coupled to the optical interface. The optical path allows transmission of the first light into the fluid at the optical interface and also allows receiving the second light from the optical interface. The second light includes one or more light components disturbed by the fluid. A processor provides digital data associated with the measurement of phases in the fluid using optical data from at least the second light.
The present disclosure is for a tool for measurement of phases in fluid in downhole applications. The tool includes a light coupler for providing a first light and for detecting a second light. The first light is provided to an optical interface and the second light is received from the optical interface. The optical interface is between the tool and the fluid. An optical path is provided that is integral or coupled to the optical interface. The optical path allows transmission of the first light into the fluid at the optical interface and also allows receiving the second light from the optical interface. The second light includes one or more light components disturbed by the fluid. A processor provides digital data associated with the measurement of phases in the fluid using optical data from at least the second light.
Embodiments of the present disclosure include a system for driving an arm (60, 80, 82) radially outward from a work string axis including a pivot block (76A, 76B) coupled to the arm at a first coupling, the arm rotating about the first coupling in a first direction to move from a stored position to an expanded position, and about the first coupling in a second direction to move from the expanded position to the stored position. The system also includes a biasing member that drives movement of the arm in the first direction. The system further includes a chamber for storing the biasing member within a pivot block diameter when the arm is in the stored position.
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
E21B 47/10 - Locating fluid leaks, intrusions or movements
Embodiments of the present disclosure include a system for positioning a sensor within a flow path of a wellbore annulus including a work string extending into the well bore annul us from a surface location. The system includes a moveable arm on the work string, the arm transitioning between a first radial location and a second radial location. The system further includes a bracket coupled to the arm, the bracket being pivotable about a pivot axis, wherein the bracket supports the sensor and transitions the sensor from a stored position to a deployed position.
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
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
Embodiments of the present disclosure include a sensor deployment system with a first bulkhead arranged at a first end of a downhole tool, a second bulkhead arranged at a second end of the downhole tool, opposite the first end, a first pivot block arranged proximate the first bulkhead, a second pivot block arranged proximate the second bulkhead, and an arm rotatably coupled to the first and second pivot blocks at opposite ends of the arm, wherein rotation of at least a portion of the arm drives at least a portion of the arm radially outward from an axis of the downhole tool.
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
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
Embodiments of the present disclosure include a system for positioning a sensor within a flow path of a wellbore annulus including a work string extending into the well bore annul us from a surface location. The system includes a moveable arm on the work string, the arm transitioning between a first radial location and a second radial location. The system further includes a bracket coupled to the arm, the bracket being pivotable about a pivot axis, wherein the bracket supports the sensor and transitions the sensor from a stored position to a deployed position.
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
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
Embodiments of the present disclosure include a deployment system including an actuator. The deployment system also includes an actuator arm coupled to the actuator. The deployment system further includes a crank rotatably coupled at a pivot point. The deployment system also includes a first link arm coupled to the actuator arm at a first end and the crank at a second end. The deployment system includes a second link arm coupled to the crank at a first end and a deployment arm at a second end, the second link arm transmitting rotational movement of the crank to the deployment arm.
Embodiments of the present disclosure include a deployment system including an actuator. The deployment system also includes an actuator arm coupled to the actuator. The deployment system further includes a crank rotatably coupled at a pivot point. The deployment system also includes a first link arm coupled to the actuator arm at a first end and the crank at a second end. The deployment system includes a second link arm coupled to the crank at a first end and a deployment arm at a second end, the second link arm transmitting rotational movement of the crank to the deployment arm.
Embodiments of the present disclosure include a sensor deployment system with a first bulkhead arranged at a first end of a downhole tool, a second bulkhead arranged at a second end of the downhole tool, opposite the first end, a first pivot block arranged proximate the first bulkhead, a second pivot block arranged proximate the second bulkhead, and an arm rotatably coupled to the first and second pivot blocks at opposite ends of the arm, wherein rotation of at least a portion of the arm drives at least a portion of the arm radially outward from an axis of the downhole tool.
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
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
11.
Sensor bracket positioned on a movable arm system and method
A system for positioning a sensor within a flow path of a wellbore annulus includes a work string extending into the wellbore annulus from a surface location. The system includes a movable arm on the work string, the arm transitioning between a first radial location and a second radial location. The system further includes a bracket coupled to the arm, the bracket being pivotable about a pivot axis, wherein the bracket supports the sensor and transitions the sensor from a stored position to a deployed position.
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
A system for driving an arm radially outward from a work string axis includes a pivot block coupled to the arm at a first coupling, the arm rotating about the first coupling in a first direction to move from a stored position to an expanded position, and about the first coupling in a second direction to move from the expanded position to the stored position. The system also includes a biasing member that drives movement of the arm in the first direction. The system further includes a chamber for storing the biasing member within a pivot block diameter when the arm is in the stored position.
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
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
Embodiments of the present disclosure include a deployment system including an actuator. The deployment system also includes an actuator arm coupled to the actuator. The deployment system further includes a crank rotatably coupled at a pivot point. The deployment system also includes a first link arm coupled to the actuator arm at a first end and the crank at a second end. The deployment system includes a second link arm coupled to the crank at a first end and a deployment arm at a second end, the second link arm transmitting rotational movement of the crank to the deployment arm.
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
F16H 21/44 - Gearings comprising primarily only links or levers, with or without slides all movement being in, or parallel to, a single plane for conveying or interconverting oscillating or reciprocating motions
14.
Sensor deployment system and method using a movable arm with a telescoping section
A sensor deployment system includes a first bulkhead arranged at a first end of a downhole tool, a second bulkhead arranged at a second end of the downhole tool, opposite the first end, a first pivot block arranged proximate the first bulkhead, a second pivot block arranged proximate the second bulkhead, and an arm rotatably coupled to the first and second pivot blocks at opposite ends of the arm. Rotation of at least a portion of the arm drives at least a portion of the arm radially outward from an axis of the downhole tool.
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
A method of monitoring the performance of a multi-phase electric motor (13), wherein the electric motor comprises a plurality of stator windings (7, 8, 9) connected in a wye configuration to form a wye point. The method comprises measuring an electrical characteristic of the wye point in a time domain; based upon the measured electrical characteristic of the wye point in the time domain, determining an electrical characteristic of the wye point in the frequency domain; and deriving data indicative of at least one parameter of the performance of the electric motor based upon the determined electrical characteristic of the wye-point in the frequency domain.
A method of monitoring the performance of a multi-phase electric motor (13), wherein the electric motor comprises a plurality of stator windings (7, 8, 9) connected in a wye configuration to form a wye point. The method comprises measuring an electrical characteristic of the wye point in a time domain; based upon the measured electrical characteristic of the wye point in the time domain, determining an electrical characteristic of the wye point in the frequency domain; and deriving data indicative of at least one parameter of the performance of the electric motor based upon the determined electrical characteristic of the wye-point in the frequency domain.
A sensor for measuring a property comprises: a radiation source, a detector and a sensing element. The radiation source is operable to produce a radiation beam. The detector is provided with a detecting surface for receiving radiation and outputting a signal in dependence on the received radiation. An aperture extends through the detector from the detecting surface to an opposed surface. The sensing element is operable to receive radiation and to reflect at least a portion of the radiation so as to form a reflected radiation beam, one or more properties of the reflected radiation beam being dependent on one or more properties to be measured. The radiation source and the sensing element are disposed on opposite sides of the detector such that the radiation source is arranged to direct the radiation beam through the aperture to the sensing element and the sensing element is arranged to direct the reflected radiation beam to the detecting surface of the detector.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01N 21/85 - Investigating moving fluids or granular solids
G01N 21/359 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light using near infrared light
A sensor for measuring a property comprises: a radiation source, a detector and a sensing element. The radiation source is operable to produce a radiation beam. The detector is provided with a detecting surface for receiving radiation and outputting a signal in dependence on the received radiation. An aperture extends through the detector from the detecting surface to an opposed surface. The sensing element is operable to receive radiation and to reflect at least a portion of the radiation so as to form a reflected radiation beam, one or more properties of the reflected radiation beam being dependent on one or more properties to be measured. The radiation source and the sensing element are disposed on opposite sides of the detector such that the radiation source is arranged to direct the radiation beam through the aperture to the sensing element and the sensing element is arranged to direct the reflected radiation beam to the detecting surface of the detector.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01N 21/85 - Investigating moving fluids or granular solids
G01N 21/359 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light using near infrared light
A downhole tool (10) operatively associated with a downhole pump (P) for use in artificial lift applications comprises a body (12) having a throughbore (14) forming an axial flow passage and a plurality of lateral ports (16) forming a lateral flow passage, a valve seat (18) for co-operating with a valve member (22) and a sleeve member (20). In use, the downhole tool (10) is run into a borehole, such as an oil and/or gas production well borehole (B), as part of a tubing string (S), the downhole tool (10) being configured to permit selective axial passage of fluid through the downhole tool (10) while lateral passage of fluid is prevented, the downhole tool (10) being operable to move from the first, closed, configuration to the second, open, configuration in response to the activation event to divert fluid through the lateral flow passage into an annulus (A) between the downhole tool (10) and the borehole (B).
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
20.
DOWNHOLE TOOL HAVING AN AXIAL PASSAGE AND A LATERAL FLUID PASSAGE BEING OPENED / CLOSED
A downhole tool (10) operatively associated with a downhole pump (P) for use in artificial lift applications comprises a body (12) having a throughbore (14) forming an axial flow passage and a plurality of lateral ports (16) forming a lateral flow passage, a valve seat (18) for co-operating with a valve member (22) and a sleeve member (20). In use, the downhole tool (10) is run into a borehole, such as an oil and/or gas production well borehole (B), as part of a tubing string (S), the downhole tool (10) being configured to permit selective axial passage of fluid through the downhole tool (10) while lateral passage of fluid is prevented, the downhole tool (10) being operable to move from the first, closed, configuration to the second, open, configuration in response to the activation event to divert fluid through the lateral flow passage into an annulus (A) between the downhole tool (10) and the borehole (B).
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
A mechanism for securing a series of fiber optic cable connectors includes a base that has several connector recesses and a lid that is removably attached to the base. The mechanism may be used to ruggedly connect a series of fiber optic cables in a downhole instrument where space is limited, with the ability to break each of the series of fiber optic cables individually.
A mechanism for securing a fibre optic cable connector includes a base that has a connector recess and a lid that is removably attached to the base. The mechanism may be used to connect a first fibre optic cable with a second fibre optic cable in a downhole instrument or in a deployment cable connected to the downhole instrument.
E21B 47/135 - 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 by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
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
A peak hold circuit configured for use in a downhole sensor includes a long tail pair circuit, a correction circuit, and a current mirror circuit. The current mirror circuit includes two current mirrors connected to a long tail pair formed by a first transistor and a second transistor. The current mirror also includes a first resistor and a second resistor connected to a third transistor. The first transistor is connected to a correction transistor of the correction circuit. The value of the first resistor is selected to be essentially equal to the same value as the second resistor so that when the long tail pair is balanced, the current flowing through a collector of the second transistor is equal to the current flowing through the first transistor, causing the correction transistor to switch off.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 49/00 - Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling 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
A method for determining the concentrations of elements within a geologic formation includes the use of an inversion algorithm that seeks to minimize a cost function (F). The method includes the use of an iterative process 200 that updates the calculated concentrations of each element at each iteration using the gradient of the cost function (F). If the method returns a negative value for any of the elemental concentrations, the corresponding derivative is set to zero and the iterative process continues. The iteration is terminated if the difference between the model and measurement becomes suitably small or if a predetermined threshold number of iterations have been taken. The results of the determination of the elemental concentrations are displayed on a computer.
G01V 5/10 - Prospecting or detecting by the use of nuclear radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
25.
SENSITIVE DC CURRENT IMBALANCE DETECTOR AND CALIBRATION METHOD
A current leakage detector (100) is configured for detecting current leakage between a power source and a load. The current leakage detector (100) includes a first sensing coil (122) and a second sensing coil (124) positioned opposite the first sensing coil (122). The current leakage detector (100) further includes a magnetic field sensor (126) proximate the first sensing coil (122) and the second sensing coil (124) and the magnetic field sensor has a response range. The current leakage detector also includes a bias circuit (132) configured to adjust the response range of the magnetic field sensor. A method for detecting current leakage includes the steps of providing a first sensing coil (122) and a second sensing coil (124). The method continues with the steps of providing a magnetic field sensor in proximity to the first and second sensing coils and providing a bias circuit. The method continues with the step of utilizing the bias circuit to place the response of the magnetic field sensor within a preferred response range.
G01R 15/20 - Adaptations providing voltage or current isolation, e.g. for high-voltage or high-current networks using galvano-magnetic devices, e.g. Hall-effect devices
G01R 31/02 - Testing of electric apparatus, lines, or components for short-circuits, discontinuities, leakage, or incorrect line connection
H02H 3/33 - Emergency protective circuit arrangements for automatic disconnection directly responsive to an undesired change from normal electric working condition, with or without subsequent reconnection responsive to phase angle between voltages or between currents involving comparison of the voltage or current values at corresponding points in different conductors of a single system, e.g. of currents in go and return conductors using summation current transformers
A gauge system and method for monitoring well pressure at temperatures in excess of 300° C. used in permanent monitoring of oil and gas wellbores. The gauge system includes an analog output transducer and a long cable which is an extruded mineral insulated multi-core cable with a seam welded corrosion resistant metal outer sheath. The transducer is enclosed in a pressure tight corrosion resistant housing and the housing is pressure sealed to the metal outer sheath. The method includes applying signal conditioning and processing to the measurements to compensate for characteristics of the transducer, the cable and the environment and thereby provide continuous monitoring of the wellbore.
G01L 7/00 - Measuring the steady or quasi-steady pressure of a fluid or a fluent solid material by mechanical or fluid pressure-sensitive elements
G01L 19/00 - MEASURING FORCE, STRESS, TORQUE, WORK, MECHANICAL POWER, MECHANICAL EFFICIENCY, OR FLUID PRESSURE - Details of, or accessories for, apparatus for measuring steady or quasi-steady pressure of a fluent medium insofar as such details or accessories are not special to particular types of pressure gauges
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
G01L 19/04 - Means for compensating for effects of changes of temperature
A data communications system and method for transmitting data over a string between a surface location and a sub-surface location in a well bore in which a load varying device at the sub-surface varies the mechanical load on the string to be indicative of the data and a load measuring apparatus at surface monitors the mechanical load on the string and decodes the data. Data transmission is described from a pump assembly through a sucker rod string. Embodiments of load varying devices using electrical generators, friction rollers and hydraulic and pneumatic brakes are also described.
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
E21B 47/16 - 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 using acoustic waves through the drill string or casing
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
A fluid measurement system and method for determining component mixtures flowing in a conduit such as an oil well. The system includes a sensor wire for location in a well bore; a signal generator for injecting a high frequency signal along the wire; a data acquisition unit to record first reflected signals received from the wire; a system criteria unit to maintain a data set relevant to the system, and a processor unit operable to act upon the first reflected signals and the data set to establish an output indicative of component fluid within the well bore from which the mixture of fluids flowing within the well bore can be determined. An iterative process can be used with waveguide and probabilistic models.
G01V 3/18 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
A three phase power system provided with a data communications system and associated method of data transmission for transmitting data over a three phase power system between a surface and a sub-surface location for an arrangement such as an oil field electrical submersible pump, the data communications system comprising a cabled connection from a surface system to a sub-surface system; a power module coupled to the cabled connection via a tuned circuit tuned to a first frequency, a data signal module coupled to the cabled connection via a tuned circuit tuned to a second frequency, independently of the coupled power module so as to minimize interference between the power signal module and data signal module during operation.
G01V 3/00 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation
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
H04B 3/54 - Systems for transmission via power distribution lines
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
A peak hold circuit configured for use in a downhole sensor includes a long tail pair circuit, a correction circuit, and a current mirror circuit. The current mirror circuit includes two current mirrors connected to a long tail pair formed by a first transistor and a second transistor. The current mirror also includes a first resistor and a second resistor connected to a third transistor. The first transistor is connected to a correction transistor of the correction circuit. The value of the first resistor is selected to be essentially equal to the same value as the second resistor so that when the long tail pair is balanced, the current flowing through a collector of the second transistor is equal to the current flowing through the first transistor, causing the correction transistor to switch off.
A peak hold circuit configured for use in a downhole sensor includes a long tail pair circuit, a correction circuit, and a current mirror circuit. The current mirror circuit includes two current mirrors connected to a long tail pair formed by a first transistor and a second transistor. The current mirror also includes a first resistor and a second resistor connected to a third transistor. The first transistor is connected to a correction transistor of the correction circuit. The value of the first resistor is selected to be essentially equal to the same value as the second resistor so that when the long tail pair is balanced, the current flowing through a collector of the second transistor is equal to the current flowing through the first transistor, causing the correction transistor to switch off.
A system and method for transmitting data over a three phase power system between a surface and a sub-surface location. A first power supply providing a first AC power signal and a second power supply providing a second AC power signal are at the surface. A first powered module and a second powered module which provides a data communications signal are at the sub-surface. A cable connection is provided between the surface and the sub-surface to transmit the power and data communication signals. The data communications signal provides an indication of power applied to the second powered module and a power signal is varied in response to the applied power. The invention finds specific application monitoring down hole equipment such as an electrical submersible pump in a wellbore.
G01V 3/00 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation
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
H04B 3/54 - Systems for transmission via power distribution lines
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
A data communications system and associated method of data transmission for transmitting data over a three phase power system between a surface and a sub-surface location for an arrangement such as an oil field electrical submersible pump, on each of the three conductors of a three phase cabled connection with an isolation mechanism operable to isolate any given conductor when a fault associated with that conductor is detected. With the system providing a separate AC signal and data transfer on each conductor isolation can be achieved while enabling continued operation.
G01V 3/00 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation
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
H04B 3/54 - Systems for transmission via power distribution lines
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
A multiphase flowmeter (10) and method of determining the proportions of two or more fluids flowing and also the flow rate of each of the fluids present in a harsh environment of multiphase fluid flow through a conduit at a well. One or more sensors (16) are mounted in the fluid flow to monitor a sensed area (22), with each sensor including electrical means in the form of a fluid identifier probe and temperature means in the form of a thermal fluid velocity heat loss sensor. An electronic circuit is present, the electronic circuit forming a resonant circuit (54) with the fluid identifier probe. A processor (24) is used to calculate the proportions of fluids present in the sensed area from the electrical property and the flow rate from the temperature differential. Spot measurements are achieved by making the sensed area substantially smaller than a cross-sectional area of the conduit.
A differential pressure-operated blanking completion tool for use at a Y- Block with an electrical submergible pump (ESP) in oil or other wells. The tool has a body having an inlet and first and second outlets, the outlets being arranged in parallel and opposite the inlet; a support member located between the outlets; a sealing element mounted on the support member and rotatable with respect to the support member, the element including a substantially spherical surface; and wherein the support member is pivoted between the outlets to bring a fresh sealing surface into contact with either outlet and thereby selectively seal the respective outlet and prevent fluid flow therethrough.
A differential pressure-operated blanking completion tool for use at a Y- Block with an electrical submergible pump (ESP) in oil or other wells. The tool has a body having an inlet and first and second outlets, the outlets being arranged in parallel and opposite the inlet; a support member located between the outlets; a sealing element mounted on the support member and rotatable with respect to the support member, the element including a substantially spherical surface; and wherein the support member is pivoted between the outlets to bring a fresh sealing surface into contact with either outlet and thereby selectively seal the respective outlet and prevent fluid flow therethrough.
A data communications system and method for transmitting data over a string between a surface location and a sub-surface location in a well bore in which a load varying device at the sub-surface varies the mechanical load on the string to be indicative of the data and a load measuring apparatus at surface monitors the mechanical load on the string and decodes the data. Data transmission is described from a pump assembly through a sucker rod string. Embodiments of load varying devices using electrical generators, friction rollers and hydraulic and pneumatic brakes are also described.
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
E21B 47/16 - 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 using acoustic waves through the drill string or casing
A fluid measurement system and method for determining component mixtures flowing in a conduit such as an oil well. The system includes a sensor wire (24) for location in a well bore (12); a signal generator (68) for injecting a high frequency signal along the wire (24); a data acquisition unit (72) to record first reflected signals received from the wire; a system criteria unit to maintain a data set relevant to the system, and a processor unit (66) operable to act upon the first reflected signals and the data set to establish an output indicative of component fluid within the well bore from which the mixture of fluids flowing within the well bore can be determined. An iterative process can be used with waveguide and probabilistic models.
A fluid measurement system (10, 110, 210) and method of fluid mix determination over a sampling length (25) in a well bore (12). A pulse generator is run in the well bore from which is suspended a cable (24) with two conductors having a length equal to the sampling length. A high frequency pulse is injected along the cable and from the detected response average propagation velocities over the various reflections are used to determine the mixture of fluids. Embodiments are described which improve the determination such as using a cable with sections of alternating impedance, helically wound cable, providing multiple signal generators, incorporating a mathematical model, analyzing the analog signal response, providing a reference cable and incorporating an optical distributed temperature sensor.
G01V 3/18 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
E21B 47/10 - Locating fluid leaks, intrusions or movements
A gauge system and method for monitoring well pressure at temperatures in excess of 300° C. used in permanent monitoring of oil and gas wellbores. The gauge system includes an analogue output transducer and a long cable which is an extruded mineral insulated multi-core cable with a seam welded corrosion resistant metal outer sheath. The transducer is enclosed in a pressure tight corrosion resistant housing and the housing is pressure sealed to the metal outer sheath. The method includes applying signal conditioning and processing to the measurements to compensate for characteristics of the transducer, the cable and the environment and thereby provide continuous monitoring of the wellbore.
G01L 19/00 - MEASURING FORCE, STRESS, TORQUE, WORK, MECHANICAL POWER, MECHANICAL EFFICIENCY, OR FLUID PRESSURE - Details of, or accessories for, apparatus for measuring steady or quasi-steady pressure of a fluent medium insofar as such details or accessories are not special to particular types of pressure gauges
A three phase power system provided with a data communications system and associated method of data transmission for transmitting data over a three phase power system between a surface and a sub-surface location for an arrangement such as an oil field electrical submersible pump, the data communications system comprising a cabled connection from a surface system to a sub- surface system; a power module coupled to the cabled connection via a tuned circuit tuned to a first frequency, a data signal module coupled to the cabled connection via a tuned circuit tuned to a second frequency, independently of the coupled power module so as to minimise interference between the power signal module and data signal module during operation.
A data communications system and associated method of data transmission for transmitting data over a three phase power system between a surface and a sub-surface location for an arrangement such as an oil field electrical submersible pump, on each of the three conductors of a three phase cabled connection with an isolation mechanism operable to isolate any given conductor when a fault associated with that conductor is detected. With the system providing a separate AC signal and data transfer on each conductor isolation can be achieved whilst enabling continued operation.
A method of high frequency data transmission for transmitting data over a three phase power system between a surface and a subsurface location, method using a first data transmit frequency and a second data transmit frequency, the data transmit frequencies being numerically distinct to each other and the data is transmitted on at least the second transmit frequency with a time delay between transmissions at each of the transmit frequencies to provide an uncorrupted data signal without interference. The invention finds specific application monitoring down hole equipment such as an electrical submersible pump in a wellbore.
A system and method for transmitting data over a three phase power system between a surface and a sub-surface location. A first power supply providing a first AC power signal and a second power supply providing a second AC power signal are at the surface. A first powered module and a second powered module which provides a data communications signal are at the sub-surface. A cable connection is provided between the surface and the sub-surface to transmit the power and data communication signals. The data communications signal provides an indication of power applied to the second powered module and a power signal is varied in response to the applied power. The invention finds specific application monitoring down hole equipment such as an electrical submersible pump in a wellbore.
A system and method for transmitting data over a three phase power system between a surface and a sub-surface location. A first power supply providing a first AC power signal and a second power supply providing a second AC power signal are at the surface. A first powered module and a second powered module which provides a data communications signal are at the sub-surface. A cable connection is provided between the surface and the sub-surface to transmit the power and data communication signals. The data communications signal provides an indication of power applied to the second powered module and a power signal is varied in response to the applied power. The invention finds specific application monitoring down hole equipment such as an electrical submersible pump in a wellbore.
A three phase power system provided with a data communications system and associated method of data transmission for transmitting data over a three phase power system between a surface and a sub-surface location for an arrangement such as an oil field electrical submersible pump, the data communications system comprising a cabled connection from a surface system to a sub- surface system; a power module coupled to the cabled connection via a tuned circuit tuned to a first frequency, a data signal module coupled to the cabled connection via a tuned circuit tuned to a second frequency, independently of the coupled power module so as to minimise interference between the power signal module and data signal module during operation.
A data communications system and associated method of data transmission for transmitting data over a three phase power system between a surface and a sub-surface location for an arrangement such as an oil field electrical submersible pump, on each of the three conductors of a three phase cabled connection with an isolation mechanism operable to isolate any given conductor when a fault associated with that conductor is detected. With the system providing a separate AC signal and data transfer on each conductor isolation can be achieved whilst enabling continued operation.
A fluid measurement system and method for determining distributed measurement of a fluid type and a fluid velocity in a wellbore, pipeline or other conduit in which fluid is moving. Measurement is made by immersing one or more cables having sequential sampling sections in the fluid and monitoring a cooling effect across a cable on the sampling sections and the response to injection of a high frequency pulse each sampling section. A probabilistic model is then used to determine the distributed velocity and fluid types along the conduit.
E21B 47/10 - Locating fluid leaks, intrusions or movements
G01F 1/688 - Structural arrangements; Mounting of elements, e.g. in relation to fluid flow using a particular type of heating, cooling or sensing element
G01F 25/00 - Testing or calibration of apparatus for measuring volume, volume flow or liquid level or for metering by volume
G01N 27/02 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance
G01D 5/26 - Mechanical means for transferring the output of a sensing member; Means for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for converting; Transducers not specially adapted for a specific variable using optical means, i.e. using infrared, visible or ultraviolet light
G01K 11/32 - Measuring temperature based on physical or chemical changes not covered by group , , , or using changes in transmittance, scattering or luminescence in optical fibres
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
G01R 27/26 - Measuring inductance or capacitance; Measuring quality factor, e.g. by using the resonance method; Measuring loss factor; Measuring dielectric constants
A fluid measurement system (10, 110, 210) and method of fluid mix determination over a sampling length (25) in a well bore (12). A pulse generator is run in the well bore from which is suspended a cable (24) with two conductors having a length equal to the sampling length. A high frequency pulse is injected along the cable and from the detected response average propagation velocities over the various reflections are used to determine the mixture of fluids. Embodiments are described which improve the determination such as using a cable with sections of alternating impedance, helically wound cable, providing multiple signal generators, incorporating a mathematical model, analysing the analogue signal response, providing a reference cable and incorporating an optical distributed temperature sensor.
An energy storage system is disclosed. The energy storage system comprises an energy storage device configured to operate above ambient temperature, and a thermal insulator at least partially surrounding the energy storage device, wherein heat losses from one or more other devices are received within the thermal insulator to provide heat energy to the energy storage device. Utilizing heat losses from one or more other devices, such as associated electronic components, enables the energy storage device to be maintained at its elevated operational temperature for longer providing extended battery life. In the application of wireline logging, this results in more data log available per trip in a well.
H01M 10/653 - Means for temperature control structurally associated with the cells characterised by electrically insulating or thermally conductive materials
H01M 10/667 - Heat-exchange relationships between the cells and other systems, e.g. central heating systems or fuel cells the system being an electronic component, e.g. a CPU, an inverter or a capacitor
H01M 10/658 - Means for temperature control structurally associated with the cells by thermal insulation or shielding
H01M 10/39 - Accumulators not provided for in groups working at high temperature
An energy storage system is disclosed. The energy storage system comprises an energy storage device arranged to operate above ambient temperature; a thermal insulator at least partially surrounding the energy storage device; and wherein heat losses from one or more other devices are received within the thermal insulator to provide heat energy to the energy storage device. Utilising heat losses from one or more other devices, such as associated electronic components, enables the energy storage device to be maintained at its elevated operational temperature for longer providing extended battery life. In the application of wireline logging, this results in more data log available per trip in a well.
H01M 10/659 - Means for temperature control structurally associated with the cells by heat storage or buffering, e.g. heat capacity or liquid-solid phase changes or transition
Apparatuses, methods for manufacturing an apparatus and methods for measuring a fluid resistivity are provided. An apparatus for measuring a fluid resistivity includes a fluid column defining structure, two current injecting electrodes, voltage measurement electrodes, and two additional electrodes. The fluid column defining structure is configured to allow a fluid, whose resistivity is to be measured, to fill a fluid column inside the fluid column defining structure. The two current injecting electrodes are configured to inject a known current into the fluid column. The voltage measurement electrodes are configured to measure a voltage across a measurement column included in the fluid column. The two additional electrodes disposed inside the fluid column defining structure, outside of the positions of the two current injecting electrodes in the longitudinal direction are electrically connected to each other.
G01V 3/18 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
A load cell for a downhole load measuring tool is provided. The load cell comprises a plurality of strain gauges arranged in a balanced array, wherein the array of strain gauges is provided in fluid which, in use, is at substantially the same pressure as the surrounding downhole fluid.
G01L 1/22 - Measuring force or stress, in general by making use of electrokinetic cells, i.e. liquid-containing cells wherein an electrical potential is produced or varied upon the application of stress using resistance strain gauges
Presented are systems and methods for dampening vibrations transmitted to a sensor assembly based on well drilling operations. Vibration isolators are distributed around a sensor assembly and retained in their desired location. The sensor assembly and retained vibration isolators are inserted in a shrinkable thin-walled tube and the thin-walled tube is shrunk to constrict the inner surface of the thin-walled tube, and the retained vibration isolators against the outer surface of the sensor assembly. Additionally, the constricted thin-walled tube restrains a wiring harness associated with the sensor assembly in a wire well traversing the axial direction of the sensor assembly.
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
55.
Canted helix collapsible flowmeter and method of measuring a fluid flow
Flowmeters and methods of measuring a fluid flow or manufacturing flowmeters are presented. A flowmeter has a tool body and one or more spinner arms configured to extend with a first end away from the tool body and a second end joined to the tool body, when deployed to measure a fluid flow. Each spinner arm includes a helical blade configured to rotate due to a fluid flowing substantially parallel to a longitudinal axis of the tool body, around a rotation axis between the first end and the second end.
G01F 1/28 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using mechanical effects by detection of dynamic effects of the flow by drag-force, e.g. vane type or impact flowmeter
G01F 1/05 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using mechanical effects
E21B 47/10 - Locating fluid leaks, intrusions or movements
56.
Multifunction downhole release tool mechanism with lost motion
Presented is a system and method for disconnecting a plurality of wireline tools from a string of wireline tools while maintaining operation of the wireline tools remaining with the string of wireline tools. The disconnection is non-destructive and allows a reconnection of the disconnected tools after retrieval from the well. The system also enables testing of the disconnection mechanism before deploying the wireline tool string into the well.
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 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
57.
MULTIFUNCTION DOWNHOLE RELEASE TOOL MECHANISM WITH LOST MOTION
Presented is a system and method for disconnecting a plurality of wireline tools from a string of wireline tools while maintaining operation of the wireline tools remaining with the string of wireline tools. The disconnection is non-destructive and allows a reconnection of the disconnected tools after retrieval from the well. The system also enables testing of the disconnection mechanism before deploying the wireline tool string into the well.
A gauge system and method for monitoring well pressure at temperatures in excess of 300° C used in permanent monitoring of oil and gas wellbores. The gauge system includes an analogue output transducer and a long cable which is an extruded mineral insulated multi-core cable with a seam welded corrosion resistant metal outer sheath. The transducer is enclosed in a pressure tight corrosion resistant housing and the housing is pressure sealed to the metal outer sheath. The method includes applying signal conditioning and processing to the measurements to compensate for characteristics of the transducer, the cable and the environment and thereby provide continuous monitoring of the wellbore.
Device and method for performing distributed fluid velocity measurement. An elongate device comprising along its length, a heated core (200), at least one outer layer (240) around the core, the outside surface of the outer layer (240) defining an outside surface of the device, and a distributed temperature sensor (230) located between the heated core (200) and the outside surface of the device. The method immerses the device in one or more fluids along its length, measures the ambient temperature of the fluids at points along it's length, heats the heated core (200) for a predetermined heating period and measures the temperature again at the same points. Using pre-installed knowledge the device can obtain distributed and/or point fluid velocity measurements.
E21B 47/10 - Locating fluid leaks, intrusions or movements
G01P 5/10 - Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft by measuring thermal variables
60.
IMPROVED METHOD OF DETERMINING A PHASE CHANGE IN A RESERVOIR
Method and apparatus to determine the relative and/or absolute position of a phase change in a fluid reservoir comprising hydrocarbons by providing a first wire in a borehole within the reservoir; providing a reference system to the first wire in the borehole; transmitting an electromagnetic signal through the first wire; detecting a detected response to the electromagnetic signal from the first wire; generating a reference response from the reference system; using the reference response to correct the detected response; and determining the phase change position using data from the corrected response. Reference systems in the form of a second wire; a transmission line and an electronic equivalent circuit simulation model; and an electrical model of the first wire and borehole, are described.
G01V 3/30 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
A pressure balancing device for a transducer is provided. The pressure balancing device comprises: a pressure transmission device having a cross-sectional area and arranged, in use, to be exposed to a fluid; and a fluid chamber having a hollow shaft, the fluid chamber being arranged to be acted on by the pressure transmission device; wherein the cross-sectional area of the hollow shaft is less than the cross-sectional area of the pressure transmission device.
A pressure balancing device for a transducer is described. The pressure balancing device has a pressure transmission device such as a piston, bladder, diaphragm or bellows for example arranged, in use, to be exposed to a fluid such as a downhole well fluid. A fluid chamber having a hollow shaft is arranged to be acted on by the pressure transmission device. The cross-sectional area of the hollow shaft is arranged to be less than that of the pressure transmission device to reduce resistance forces. The hollow shaft may be a load transmission shaft which may be connected to a load sensor.
G01D 3/028 - Measuring arrangements with provision for the special purposes referred to in the subgroups of this group mitigating undesired influences, e.g. temperature, pressure
G01L 1/26 - Auxiliary measures taken, or devices used, in connection with the measurement of force, e.g. for preventing influence of transverse components of force, for preventing overload
G01L 19/06 - Means for preventing overload or deleterious influence of the measured medium on the measuring device or vice versa
A load cell for a downhole load measuring tool is described. The load cell comprises a plurality of strain gauges arranged in a balanced array such as a Wheatstone Bridge. The array of strain gauges is provided in fluid which, in use, is at the same pressure as the surrounding downhole fluid. As the balanced array is at the same pressure as the surrounding fluid, there is no requirement to pressure calibrate the load cell. The load cell is preferably arranged to measure shear strain across the load cell.
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 apparatus for determining the concentration of a conductive fluid present in a fluid filled bore hole is described. Such apparatus are known as water hold-up meters and are frequently used in oil, gas and water filled bore holes. In bore hole applications, data bandwidth between a down hole device and the surface can be limited, while determining water hold-up based on down hole measurements can be data intensive. A technique is proposed for calculating the water hold up that requires less data to be transmitted between the down hole device and the surface.
G01V 3/18 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
G01V 3/34 - Transmitting data to recording or processing apparatus; Recording data
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
G06F 3/00 - Input arrangements for transferring data to be processed into a form capable of being handled by the computer; Output arrangements for transferring data from processing unit to output unit, e.g. interface arrangements
E21B 47/10 - Locating fluid leaks, intrusions or movements
G01N 27/07 - Construction of measuring vessels; Electrodes therefor
A method of transmitting power and/or data between downhole equipment and a surface through a circuit including an alternating current (AC) powered motor and its associated power cable for powering the downhole equipment is disclosed, where the data is transmitted at frequencies outside the normal operating ranges that are thought acceptable. Associated circuitry and apparatus for performing the method are disclosed.
A modulator is disclosed for creating a pressure pulse in a fluid-filled well. The modulator comprises a tool body on which a plurality of extendable arms are mounted. The arms may be retracted into a stowed position substantially adjacent the tool body, or may be extended to meet the wall of the borehole. The arms are preferably resilient bowsprings that may be flexed outwards from the tool by means of an actuator pushing on at least one end of the springs. A flexible valve sleeve or bag is suspended between the arms and cooperates with a valve mounted adjacent the sleeve on the tool body. The valve sleeve creates a fluid-flow path through the valve, and in operation, the valve closes one end of the valve sleeve to create the pressure pulse. Sealing of the valve sleeve against the wall of the well is a result of the fluid pressure inflating the sleeve against the well wall. As a result, sealing takes place over an extended area of the bag and is dynamically responsive to changes in fluid flow or pressure.
A modulator is disclosed for creating a pressure pulse in a fluid-filled well. The modulator comprises a tool body on which a plurality of extendable arms (6) are mounted. The arms (6) may be retracted into a stowed position substantially adjacent the tool body, or may be extended to meet the wall of the borehole (2). The arms (6) are preferably resilient bowsprings that may be flexed outwards from the tool by means of an actuator pushing on at least one end of the springs. A flexible valve sleeve (5) or bag is suspended between the arms (6) and cooperates with a valve (4) mounted adjacent the sleeve on the tool body. The valve sleeve (5) creates a fluid-flow path through the valve (4), and in operation, the valve (4) closes one end of the valve sleeve (5) to create the pressure pulse. Sealing of the valve sleeve against the wall of the well is a result of the fluid pressure inflating the sleeve against the well wall. As a result, sealing takes place over an extended area of the bag and is dynamically responsive to changes in fluid flow or pressure.
E21B 47/18 - 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 using acoustic waves through the well fluid
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
68.
Method and apparatus for determining the permeability of earth formations
A method and apparatus for determining the fluid permeability of an earth formation is described. An instrument comprising an acoustic source and acoustic and electrokinetic sensors is located in a borehole at a site of interest. The acoustic source is fired and the resulting variations in pressure and electric field generated are measured and recorded. The Biot equation, and an equation for the streaming potential coupled to fluid displacement terms, is solved using finite element analysis to give an expected pressure waveform and electrokinetic waveform based on estimated earth formation properties. By comparison of the measured waveforms and those calculated from the equations, the actual permeability of the earth formation can be deduced.
G01V 1/40 - Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
G01V 3/18 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
G01V 3/00 - Electric or magnetic prospecting or detecting; Measuring magnetic field characteristics of the earth, e.g. declination or deviation
G01V 9/00 - Prospecting or detecting by methods not provided for in groups
An apparatus for determining the concentration of a conductive fluid present in a fluid filled bore hole is described. Such apparatus are known as water hold-up meters and are frequently used in oil, gas and water filled bore holes. In bore hole applications, data bandwidth between a down hole device and the surface can be limited, while determining water hold-up based on down hole measurements can be data intensive. A technique is proposed for calculating the water hold up that requires less data to be transmitted between the down hole device and the surface.
A method of transmitting power and/or data between downhole equipment and a surface through a circuit including an alternating current (AC) powered motor and itsassociated power cable for powering the downhole equipmentis disclosed, where the data is transmitted atfrequencies outside the normal operating ranges that are thought acceptable. Associated circuitry and apparatus for performing the method are disclosed.
A method of transmitting power and/or data between downhole equipment and a surface through a circuit including an alternating current (AC) powered motor and itsassociated power cable for powering the downhole equipmentis disclosed, where the data is transmitted atfrequencies outside the normal operating ranges that are thought acceptable. Associated circuitry and apparatus for performing the method are disclosed.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
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
72.
IMPROVEMENTS IN OR RELATING TO ESP COMPLETION SYSTEMS
A completion system (34) for use with electrical submergible pumps (ESP) has an assembly (36) including a tubular body (41), incorporating an auto-blanking valve (50) with radial outlets (58) in a retrievable insert (38) alignable with radial ports (75) in an inner moveable valve sleeve (76) surrounding part of a throughbore (46), wherein, dependent upon fluid flow pressure acting upon a valve poppet (81) on the sleeve, radial outlets (58) of the shunt valve can be aligned with the radial outlets (45) of the body such that if the ESP is switched off, the shunt valve operates to pass fluid from the production tubing out of the body into the well bore.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
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
Completion system (120) has an auto-flow crossover assembly (10), with a plurality of selectable electrical submergible pumps (ESP) (114, 116), e.g. As a dual primary and back-up ESP system, the assembly including a tubular body (38), within which is an annulus (44) housing a shunt valve (50) with radial outlets (58) alignable with radial inner ports (75) in an inner moveable valve sleeve (76) surrounding part of a throughbore (46), wherein, dependent upon pump selection, and fluid pressure acting upon a valve poppet (81) on the sleeve to lift same from a valve seat (60), the radial ports (58, 75) will be aligned or not permitting alternative flow path configurations in which even with both pumps turned off at least one pump is protected from fouling with detritus, and during switch over between ESPs the auto-crossover system protects the 'off' pump.
A Method and apparatus for determining the fluid permeability of an earth formation is described. An instrument (6) comprising an acoustic source (14, 16) and acoustic (18) and electrokinetic sensors (20) is located in a borehole (4) at a site of interest. The acoustic source is fired and the resulting variations in pressure and electric field generated are measured and recorded. The Biot equation, and an equation for the streaming potential coupled to fluid displacement terms, is solved using finite element analysis to give an expected pressure waveform and electrokinetic waveform based on estimated earth formation properties. By comparison of the measured waveforms and those calculated from the equations, the actual permeability of the earth formation can be deduced.
09 - Scientific and electric apparatus and instruments
37 - Construction and mining; installation and repair services
Goods & Services
Machines and machine tools for use in the construction, maintenance, repair and inspection of oil and gas wells and pipelines; centralisers, knuckle joints and swivels for use in the construction, maintenance, repair and inspection of oil and gas wells and pipelines. Scientific, surveying, electric, measuring, signaling and checking apparatus and instruments for use in the construction, maintenance, repair and inspection of oil and gas wells and pipelines; cameras, video apparatus, telemetry apparatus, data acquisition software, data processing equipment and logging apparatus including pressure, temperature, fluid density, flow rate and radiation measuring apparatus, all for use in the construction, maintenance, repair and inspection of oil and gas wells and pipelines. Services relating to the construction, maintenance, repair and inspection of oil and gas wells and pipelines; rental of apparatus relating to the construction, maintenance, repair and inspection of oil and gas wells and pipelines.
09 - Scientific and electric apparatus and instruments
Goods & Services
Computer hardware and software for use in recording and analyzing data from wells; electronic apparatus for recording and analyzing data from wells, namely, video cameras, calipers, and electronic sensors
