Single trip liner setting and drilling assembly and methods

A liner assembly ( 100 ) includes a drill string ( 120 ) to drill a borehole ( 105 ) in a formation ( 110 ). The liner assembly further includes a liner assembly releasably coupled to the drill string to move with the drill string in the borehole while the drill string drills, and to be released from the drill string in the borehole after the drill string drills to a depth.

Mud pulse telemetry

Mud pulse telemetry. The various embodiments are directed to methods and systems of encoding data in a mud pulse telemetry system, where at least a portion of the data is encoded the time between pressure transitions. Moreover, the various embodiments are directed to detection methods and systems that detect the pressure transitions at the surface.

Anti-Extrusion Seal for High Temperature Applications

A sealing system between a tubular and a chassis. In some embodiments, the sealing system includes a sealing member and an outer ring. The sealing member is compressed between the chassis and the tubular. The sealing member has a temperature and comprises a resilient material that is expandable as the temperature increases and contractible as the temperature decreases. The outer ring is displaceable to close an annulus between an outer surface of the outer ring and the inner surface of the tubular by expansion of the sealing element, whereby the sealing member is prevented from extruding into the annulus. Further, the outer ring comprises a compliant material that is deformable under load from the sealing element as the sealing element expands. 1. A sealing system comprising:a sealing member compressed between a chassis and a tubular, the sealing member comprising a temperature and comprising a resilient material that is expandable as the temperature increases and contractible as the temperature decreases; andan outer ring;wherein the outer ring is displaceable to close an annulus between an outer surface of the outer ring and the inner surface of the tubular by expansion of the sealing element, whereby the sealing member is prevented from extruding into the annulus; andwherein the outer ring comprises a compliant material that is deformable under load from the sealing element as the sealing element expands.2. The sealing system of claim 1 , wherein the outer ring slideably engages a radially extending surface of the chassis and has an angular surface engaging the sealing member claim 1 , wherein the outer ring is radially displaceable when the sealing member expands against the outer ring and the outer ring slides along the radially extending surface of the chassis.3. The sealing system of claim 1 , further comprising a preload ring claim 1 , wherein the sealing member is disposed between the outer ring and the preload ring claim 1 , the preload ring operable to ...

Drill String Tubular with a Detection System Mounted Therein

A measurement system for collecting data. In some embodiments, the measurement system includes a tubular suspended downhole, the tubular having an outer surface and a flowbore extending therethrough, the flowbore conveying a fluid, a first recess formed in the outer surface of the tubular, a first detection system mounted in the first recess, a second recess formed in the outer surface of the tubular, and a second detection system mounted in the second recess. The second recess is offset relative to the first recess by at least one of an axial distance and a circumferential distance. The first detection system is operable to measure a portion of the data, and the second detection system operable to measure another portion of the data. 1. A measurement system for collecting data , the measurement system comprising:a tubular suspended downhole, the tubular comprising an outer surface and a flowbore extending therethrough, the flowbore conveying a fluid;a first recess formed in the outer surface of the tubular;a first detection system mounted in the first recess, the first detection system operable to measure a portion of the data;a second recess formed in the outer surface of the tubular, the second recess offset relative to the first recess by at least one of an axial distance and a circumferential distance; anda second detection system mounted in the second recess, the second detection system operable to measure another portion of the data.2. The measurement system of claim 1 , wherein the tubular is a drill collar and wherein the fluid is a drilling fluid.3. The measurement system of claim 1 , wherein the data is radiation measurements.4. The measurement system of claim 1 , wherein the second recess is axially offset and circumferentially offset relative to the first recess.5. The measurement system of claim 1 , wherein the first detection system and the second detection system are electrically coupled with components positioned uphole therefrom claim 1 , the first ...

Downhole instrument calibration during formation survey

A downhole sensor calibration apparatus includes a rotational or gimbaling mechanism for guiding a sensing axis of an orientation responsive sensor through a three-dimensional orbit about three orthogonal axes. A method includes using measurements taken over the three-dimensional orbit to calibrate the sensor and determine other characteristics of the sensor or tool.

MUD PULSE TELEMETRY

Mud pulse telemetry. The various embodiments are directed to methods and systems of encoding data in a mud pulse telemetry system, where at least a portion of the data is encoded the time between pressure transitions. Moreover, the various embodiments are directed to detection methods and systems that detect the pressure transitions at the surface. 1. A computer-readable storage medium storing a program that , when executed by a processor , causes the processor to:read values indicative of pressure within a pipe that has drilling fluid flowing therein, the drilling fluid carries pressure pulses that encode data; calculate a running average time series with each datum in the running average time series being an average of the values indicative of pressure within a predetermined window of values;', 'create a filtered pressure time series from the values indicative of pressure;', 'detect negative pressure transitions in the filtered pressure time series that correspond in time to the running average time series reaching a first predetermined value and the running average time series having a first slope; and', 'detect positive pressure transitions in the filtered pressure time series that correspond in time to the running average time series reaching a second predetermined value and the running average time series having a second slope; and, 'detect, in the values indicative of pressure, pressure transitions associated with the pressure pulses by causing the processor todetermine from an amount of time between pressure transitions at least a portion of the data encoded in the pressure pulses.2. The computer-readable medium of further comprising:wherein when the processor detects, the program further causes the processor to detect negative pressure transitions in the filtered pressure time series that correspond in time to the running average time series reaching the first predetermined value and first slope being a negative slope; anddetect positive pressure ...

Apparatus and Method for Detecting Pressure Signals

An apparatus for detecting data in a fluid pressure signal in a conduit comprises an optical fiber loop comprises a measurement section and a delay section wherein the measurement section is disposed substantially circumferentially around at least a portion of the conduit, and wherein the measurement section changes length in response to the fluid pressure signal in the conduit. A light source injects a first optical signal in a first direction into the measurement section and a second optical signal in a second direction opposite the first direction into the delay section. An optical detector senses an interference phase shift between the first optical signal and the second optical signal and outputs a first signal related thereto. 1. An apparatus for detecting data in a fluid pressure signal in a conduit comprising:an optical fiber loop comprising a measurement section and a delay section wherein the measurement section is disposed substantially circumferentially around at least a portion of the conduit and wherein the measurement section changes length in response to the fluid pressure signal in the conduit;a light source injecting a first optical signal in a first direction into the measurement section and a second optical signal in a second direction opposite the first direction into the delay section; andan optical detector to sense an interference phase shift between the first optical signal and the second optical signal and outputting a first signal related thereto.2. The apparatus of wherein the first signal is related to a time derivative of the fluid pressure signal in the conduit.3. The apparatus of wherein the measurement section and the delay section are sequentially disposed.4. The apparatus of further comprising a controller in data communication with the optical detector wherein the controller integrates the first signal with respect to time and generates an output signal substantially similar to the fluid pressure signal.5. The apparatus of wherein ...

Apparatus and Method for Detecting Pressure Signals

An apparatus comprising an encoded pressure signal propagating in a fluid flowing in a conduit. An optical fiber measurement element has a reflector on one end and is disposed around at least a portion of the conduit. A light source injects a second optical signal and a third optical signal propagating in first and second optical fibers, respectively. A delay section is disposed in the second optical fiber. The second optical signal and the third optical signal are directed into the optical fiber measurement element and are reflected back from the reflective end such that at least a portion of the reflected second and third optical signals propagate through the second and first optical fibers respectively to an optical detector. The optical detector senses an interference between the reflected optical signals and outputs a first signal related thereto. 1. An apparatus comprising:an optical fiber measurement element disposed around at least a portion of a conduit;a reflector coupled to one end of the conduit;a light source injecting a first optical signal into a first beam splitter/coupler to split the first optical signal into a second optical signal propagating in a first optical fiber and a third optical signal propagating in a second optical fiber;a delay section disposed in the second optical fiber;a second beam splitter/coupler to combine and direct the second optical signal and the third optical signal into the optical fiber measurement element to the reflector, the reflector reflecting the second optical signal and the third optical signal back through the second beam splitter/coupler such that at least a portion of the reflected second optical signal propagates through the second optical fiber and at least a portion of the third optical signals propagates through the first optical fiber; andan optical detector sensing an interference between the reflected second optical signal and the reflected third optical signal caused by an encoded pressure signal ...

MAGNETOSTRICTIVE POWER SUPPLY FOR BOTTOM HOLE ASSEMBLY WITH ROTATION-RESISTANT HOUSING

A power supply includes a rotor having an undulated surface () and a magnetostrictive material disposed adjacent to the undulated surface. The undulated surface alternatingly compresses the magnetostrictive material as the rotor rotates, inducing an electric current in a conductor coupled to the magnetostrictive material. 1. A power supply comprising:a rotor comprising an undulated surface; anda magnetostrictive material disposed adjacent to the undulated surface;wherein the undulated surface alternatingly compresses the magnetostrictive material as the rotor rotates, inducing an electric current in a conductor coupled to the magnetostrictive material.2. The power supply of claim 1 , further comprising:a magnetostrictive array comprising the magnetostrictive material in a plurality of members disposed adjacent to the undulated surface.3. The power supply of claim 1 , wherein the rotor comprises:a shaft rotatably coupled with a cam rotor, wherein the cam rotor comprises the undulated surface.4. The power supply of claim 1 , further comprising:a magnetostrictive array comprising the magnetostrictive material in a plurality of members disposed adjacent to the undulated surface; andwherein the rotor comprises a shaft, and the plurality of members is oriented along an axis of the shaft.5. The power supply of claim 4 , wherein the rotor comprises the undulated surface and a flat-faced member claim 4 , and wherein the plurality of members is disposed between the undulated surface and the flat-faced member.6. The power supply of claim 1 , further comprising:a magnetostrictive array comprising the magnetostrictive material in a plurality of members disposed adjacent to the undulated surface; andwherein the rotor comprises a shaft, and the plurality of members is oriented radially with respect to an axis of the shaft.7. The power supply of . wherein the undulated surface comprises a symmetrical pattern.8. The power supply of claim 2 , further comprising:a conductor ...

HYDRAULIC PUMP WITH SOLID-STATE ACTUATOR

A hydraulic pump includes a port and a piston assembly fluidically coupled to the port. The piston assembly includes a piston and a solid-state actuator, where a shape change of the solid-state actuator is induced when a field is applied to the solid-state actuator, and where alternating shape changes of the solid-state actuator provide reciprocating movement to the piston. 1. A hydraulic pump comprising:a port; 'a piston; and', 'a piston assembly fluidically coupled to the port, wherein the piston assembly comprisesa solid-state actuator, wherein a shape change of the solid-state actuator is induced when a field is applied to the solid-state actuator, and wherein alternating shape changes of the solid-state actuator provide reciprocating movement to the piston.2. The hydraulic pump of claim 1 , wherein the field is a magnetic field.3. The hydraulic pump of claim 1 , wherein the field is an electric field.4. The hydraulic pump of claim 1 , wherein the port comprises an inlet or an outlet.5. The hydraulic pump of claim 1 , wherein the solid-state actuator comprises one or both of a magnetostrictive material and a piezoelectric material.6. The hydraulic pump of claim 1 , wherein the piston assembly further comprises:a coil disposed about the solid-state actuator to apply the field to the solid-state actuator.7. The hydraulic pump of claim 1 , further comprising an inlet valve and an outlet valve to rectify fluid flow through the port.8. The hydraulic pump of claim 1 , further comprising an inlet valve and an outlet valve fluidically coupled to the piston to facilitate a steady flow passage.9. The hydraulic pump of claim 1 , wherein the solid-state actuator comprises a stack of plates connected in parallel claim 1 , wherein the plates comprise piezoelectric material or magnetostrictive material.10. The hydraulic pump of claim 1 , wherein the piston assembly is part of an arrangement of piston assemblies to be driven together.11. The hydraulic pump of claim 10 , wherein ...

DOWNHOLE INSTRUMENT CALIBRATION DURING FORMATION SURVEY

A downhole sensor calibration apparatus includes a rotational or gimbaling mechanism for guiding a sensing axis of an orientation responsive sensor through a three-dimensional orbit about three orthogonal axes. A method includes using measurements taken over the three-dimensional orbit to calibrate the sensor and determine other characteristics of the sensor or tool. 1. A downhole sensor calibration apparatus comprising:a body having an axis; anda rotational mechanism supported by the body, the mechanism including at least one sensor;wherein the rotational mechanism is operable to rotate the sensor relative to three orthogonal axes.2. The apparatus of wherein the rotational mechanism is operable to rotate the sensor in three orthogonal planes.3. The apparatus of wherein the rotational mechanism includes an outer cage rotatable about the body axis claim 1 , and a sensor chassis supported in the outer cage and rotatable about an axis orthogonal to the body axis.4. The apparatus of wherein the rotational mechanism comprises a gimbaling mechanism.5. The apparatus of wherein the at least one sensor comprises an orientation responsive sensor wherein a sensing axis of the sensor is sensitive to the orientation of the sensor.6. The apparatus of wherein the at least one sensor comprises an accelerometer claim 5 , a magnetometer claim 5 , an inclinometer claim 5 , a gyroscope claim 5 , or a combination thereof.7. The apparatus of wherein the rotational mechanism contains a second sensor.8. The apparatus of wherein a second sensor is mounted outside of the rotational mechanism.9. The apparatus of wherein the sensor chassis comprises:rotational support members to rotate a sensing axis of the sensor about the orthogonal axis; anda gear;wherein the gear is rotatably coupled to a second gear;wherein the gears comprise interlocking, beveled gears; andwherein the second gear is coupled to a rotatable shaft.10. The apparatus of wherein the rotational mechanism is operable to move a ...

SINGLE TRIP LINER SETTING AND DRILLING ASSEMBLY

A liner assembly () includes a drill string () to drill a borehole () in a formation (). The liner assembly further includes a liner assembly releasably coupled to the drill string to move with the drill string in the borehole while the drill string drills, and to be released from the drill string in the borehole after the drill string drills to a depth. 1. A liner assembly , comprising:a drill string to drill a borehole in a formation; anda liner assembly releasably coupled to the drill string to move with the drill string in the borehole while the drill string drills, and to be released from the drill string in the borehole after the drill string drills to a depth.2. The liner assembly of claim 1 , wherein the liner assembly comprises a liner hanger coupled to a liner.3. The liner assembly of claim 2 , wherein the liner hanger is expandable.4. The liner assembly of claim 1 , further comprising:a setting tool to set the liner assembly.5. The liner assembly of claim 4 , wherein the liner assembly comprises a liner hanger that is expandable.6. The liner assembly of claim 5 , wherein the setting tool comprises a port to allow expansion of the liner hanger based claim 5 , at least in part claim 5 , on movement of a piston.7. The liner assembly of claim 5 , wherein the setting tool allows expansion of the liner hanger based claim 5 , at least in part claim 5 , on displacement of a ball or a dart through the drill string.8. The liner assembly of claim 5 , wherein the setting tool sealingly engages a surface of the liner hanger.9. The liner assembly of claim 1 , further comprising:a latch device, wherein the liner assembly is releasably coupled to the drill string based, at least in part, on the latch device.10. The liner assembly of claim 9 , wherein the latch device permits transfer of one or more of an axial force and a rotation force between the drill string and the liner assembly.11. The liner assembly of claim 9 , further comprising:a lower latch device, wherein the ...

MUD PULSE TELEMETRY

Mud pulse telemetry. The various embodiments are directed to methods and systems of encoding data in a mud pulse telemetry system, where at least a portion of the data is encoded the time between pressure transitions. Moreover, the various embodiments are directed to detection methods and systems that detect the pressure transitions at the surface. 1. A computer-readable storage medium storing a program that , when executed by a processor , causes the processor to:read values indicative of pressure within a pipe that has drilling fluid flowing therein, the drilling fluid carries pressure pulses that encode data; create a filtered pressure time series from the values indicative of pressure;', 'take the absolute value of the filtered pressure time series; and', 'detect pressure transitions as pressure spikes in the absolute value of the filtered pressure time series;, 'detect, in the values indicative of pressure, pressure transitions associated with the pressure pulses by causing the processor todecode from an amount of time between pressure transitions at least a portion of the data encoded in the drilling fluid.2. The computer-readable medium of wherein when the processor reads claim 1 , the program causes the processor to read values indicative of pressure within the pipe that carries pressure pulses created by a down hole device.3. The computer-readable medium of wherein when the processor creates the filtered pressure time series claim 1 , the program causes the processor to high-pass filter the values indicative of pressure.4. The computer-readable storage medium of wherein when the processor reads values claim 1 , the program further causes the processor to at least one selected from the group consisting of: read values indicative of pressure from a pressure transducer; reading values indicative of changes in pressure from a transducer.5. A telemetry detection method comprising:reading, by a computer system coupled to a pressure transducer, values indicative ...

POWER PRODUCTION IN A COMPLETED WELL USING MAGNETOSTRICTIVE MATERIALS

A device for generating electrical energy from mechanical motion includes a magnetostrictive generator configured to be mechanically coupled to a power conveyance path in a well bore. The power conveyance path is configured to experience an axial force change, and the magnetostrictive generator includes at least one magnetostrictive element that experiences a corresponding force change that results in a change in magnetic permeability in the at least one magnetostrictive element resulting, and is configured to experience a change in magnetic flux in a least one component that is electromagnetically coupled to at least one conductive coil, and the conductive coil is configured to generate electricity due to these magnetic flux changes. 1. A device for generating electrical energy from mechanical motion , the device comprising:a magnetostrictive generator configured to be mechanically coupled to a power conveyance path in a well bore, wherein the power conveyance path is configured to experience an axial force change, and wherein the magnetostrictive generator comprises at least one magnetostrictive element that experiences a corresponding force change that results in a change in magnetic permeability in the at least one magnetostrictive element resulting, and is configured to experience a change in magnetic flux in a least one component that is electromagnetically coupled to at least one conductive coil, and the conductive coil is configured to generate electricity due to these magnetic flux changes.2. The device of claim 1 , further comprising:a force modification unit coupled to the power conveyance path, wherein the force modification unit is configured to receive an input force based on a substantially continuous sinusoidal movement of a pump jack and to output multiple discrete fractional movements representative of portions of the input force.3. The device of claim 2 , wherein the force modification unit comprises a rack and pinion period multiplier.4. The ...

Evaluating Wellbore Telemetry Systems

Evaluating wellbore telemetry systems. Multiple evaluation signals are serially transmitted to multiple serially connected components of a wellbore telemetry system disposed in a wellbore. Each component is addressable by a respective one of the multiple evaluation signals. In response to serially transmitting the multiple evaluation signals, multiple communication links to the multiple components are evaluated based on a respective multiple responses to the multiple evaluation signals. 1. A computer-implemented method to evaluate a wellbore telemetry system , the method comprising:serially transmitting a plurality of evaluation signals to a plurality of serially connected components of a wellbore telemetry system disposed in a wellbore, each component addressable by a respective one of the plurality of evaluation signals; andin response to serially transmitting the plurality of evaluation signals, evaluating a plurality of communication links to the plurality of components based on a respective plurality of responses to the plurality of evaluation signals; and transmitting an evaluation signal to the component a threshold number of times;', 'determining a number of responses to transmitting the evaluation signal to the component the threshold number of times; and', 'determining a ratio of the number of responses to the threshold number of times the evaluation signal is transmitted to the component., 'wherein evaluating a communication link to a component based on a response to a respective one of the plurality of evaluation signals transmitted to the component comprises2. (canceled)3. The method of claim 1 , further comprising determining that the communication link to the component has failed if the ratio is less than a threshold ratio.4. A computer-implemented method to evaluate a wellbore telemetry system claim 1 , the method comprising:serially transmitting a plurality of evaluation signals to a plurality of serially connected components of a wellbore telemetry ...

ROTARY TO LINEAR CONVERTER FOR DOWNHOLE APPLICATIONS

A device generates electrical energy from mechanical motion in a downhole environment. The device converts rotary motion into a linear strain in a magnetostrictive material. The device includes a rotor, a magnetostrictive element, and an electrically conductive coil. The rotor rotates within a stator of a drill string. The magnetostrictive element is attached to the rotor by a first ball joint. The magnetostrictive element is configured to experience axial strain in response to rotational movement of the rotor. The magnetostrictive element includes a second ball joint on an end of the magnetostrictive element opposite the first ball joint. The electrically conductive coil is disposed in proximity to the magnetostrictive element. The electrically conductive coil is configured to generate an electrical current in response to a change in flux density of the magnetostrictive element. 1. A device for converting rotary motion into a linear strain and generating electrical energy , the device comprising:a rotor to rotate within a stator of a drill string;a magnetostrictive element attached to the rotor by a first ball joint, wherein the magnetostrictive element is configured to experience axial strain in response to rotational movement of the rotor, wherein the magnetostrictive element comprises a second ball joint on an end of the magnetostrictive element opposite the first ball joint; andan electrically conductive coil disposed in proximity to the magnetostrictive element, wherein the coil is configured to generate an electrical current in response to a change in flux density of the magnetostrictive element.2. The device of claim 1 , wherein the first ball joint rotates with the rotor claim 1 , wherein magnetostrictive element is configured to experience axial strain in response to the relative movement between the two ball joints.3. The device of claim 1 , further comprising:a plurality of magnetostrictive elements; anda plurality of electrically conductive coils.4. The ...

VIBRATION ENERGY HARVESTER

The system is a drilling bearing device. The device includes an outer body structure, and inner body structure, and a loading structure. The inner body structure is disposed at least partially within the outer body structure. The inner body structure moves relative to the outer body structure. The loading structure is disposed between the outer body structure and the inner body structure. The loading structure facilitates adjustment of a position of the inner body structure relative to the outer body structure relative to the outer body structure resulting from mechanical wear in the device. The loading structure substantially prevents displacement of the inner body structure relative to the outer body structure in response to a reciprocating displacement to maintain a substantially constant relative location. 1. A drilling bearing device comprising:an outer body structure;an inner body structure disposed at least partially within the outer body structure, the inner body structure configured to move relative to the outer body structure; anda loading structure disposed between the outer body structure and the inner body structure, the loading structure to facilitate adjustment of a position of the inner body structure relative to the outer body structure in response to a unidirectional displacement of the inner body structure relative to the outer body structure resulting from mechanical wear in the device, wherein the loading structure is configured to substantially prevent displacement of the inner body structure relative to the outer body structure in response to a reciprocating displacement to maintain a substantially constant relative location.2. The device of claim 1 , wherein the unidirectional displacement is due to at least one of a list of causes claim 1 , the list comprising bearing wear claim 1 , thermal expansion claim 1 , and component erosion.3. The device of claim 1 , wherein adjustment of the position of the inner body structure relative to the outer ...

MUD PULSE TELEMETRY

Mud pulse telemetry. The various embodiments are directed to methods and systems of encoding data in a mud pulse telemetry system, where at least a portion of the data is encoded the time between pressure transitions. Moreover, the various embodiments are directed to detection methods and systems that detect the pressure transitions at the surface. 1. A computer-readable storage medium storing a program that , when executed by a processor , causes the processor to:read values indicative of pressure within a pipe that has drilling fluid flowing therein, the drilling fluid carries pressure pulses that encode data; create a filtered pressure time series from the values indicative of pressure;', 'take the absolute value of the filtered pressure time series; and', 'detect pressure transitions as pressure spikes in the absolute value of the filtered pressure time series;, 'detect, in the values indicative of pressure, pressure transitions associated with the pressure pulses by causing the processor todecode from an amount of time between pressure transitions at least a portion of the data encoded in the drilling fluid.2. The computer-readable medium of wherein when the processor reads claim 1 , the program causes the processor to read values indicative of pressure within the pipe that carries pressure pulses created by a down hole device.3. The computer-readable medium of wherein when the processor creates the filtered pressure time series claim 1 , the program causes the processor to high-pass filter the values indicative of pressure.4. The computer-readable storage medium of wherein when the processor reads values claim 1 , the program further causes the processor to at least one selected from the group consisting of: read values indicative of pressure from a pressure transducer; reading values indicative of changes in pressure from a transducer.5. A telemetry detection method comprising:reading, by a computer system coupled to a pressure transducer, values indicative ...

Apparatus and method for detecting pressure signals

An apparatus comprising an encoded pressure signal propagating in a fluid flowing in a conduit. An optical fiber measurement element has a reflector on one end and is disposed around at least a portion of the conduit. A light source injects a second optical signal and a third optical signal propagating in first and second optical fibers, respectively. A delay section is disposed in the second optical fiber. The second optical signal and the third optical signal are directed into the optical fiber measurement element and are reflected back from the reflective end such that at least a portion of the reflected second and third optical signals propagate through the second and first optical fibers respectively to an optical detector. The optical detector senses an interference between the reflected optical signals and outputs a first signal related thereto.

Mud pulse telemetry

Mud pulse telemetry. The various embodiments are directed to methods and systems of encoding data in a mud pulse telemetry system, where at least a portion of the data is encoded the time between pressure transitions. Moreover, the various embodiments are directed to detection methods and systems that detect the pressure transitions at the surface.

Rotating systems associated with drill pipe

Methods and apparatuses for drilling a borehole are disclosed. An electric motor electrically and mechanically coupled to a wired drill pipe is provided. The electric motor couples to a shaft that rotates when power is supplied to the electric motor. The shaft is couplable to a drill bit. The wired drill pipe transfers electricity to the electric motor from the surface. Operation of the electric motor rotates the shaft. The drill bit wears away earth to form the borehole in the earth.

Providing a local response to a local condition in an oil well

A method and apparatus for provid-ing a local response to a local condition in an oil well are disclosed. A sensor is provided to detect a lo-cal condition in a drill string. A controllable element is provided to modulate energy in the drill string. A controller is coupled to the sensor and to the control-lable element. The controller receives a signal from the sensor, the signal indicating the presence of said local condition, processes the signal to determine a lo-cal energy modulation in the drill string to modify said local condition, and sends a signal to the controllable element to cause the determined local energy modu-lation.

A drill string tubular with a detection system mounted therein

A measurement system for collecting data. In some embodiments, the measurement system includes a tubular suspended downhole, the tubular having an outer surface and a flowbore extending therethrough, the flowbore conveying a fluid, a first recess formed in the outer surface of the tubular, a first detection system mounted in the first recess, a second recess formed in the outer surface of the tubular, and a second detection system mounted in the second recess. The second recess is offset relative to the first recess by at least one of an axial distance and a circumferential distance. The first detection system is operable to measure a portion of the data, and the second detection system operable to measure another portion of the data.

Dual channel downhole telemetry

Method and apparatus for nuclear magnetic resonance measuring while drilling

A NMR measurement-while-drilling tool has a permanent magnet (12) with a magnetic field direction substantially perpendicular to the axis of the borehole (36), a steel collar (10) of a non-magnetic material surrounding the magnet, antenna (14) positioned outside the collar, and a soft magnetic material positioned in a predetermined relationship with the collar and the magnet that helps to shape the magnetic field of the tool.

A drill string tubular with a detection system mounted therein

A measurement system for collecting data. In some embodiments, the measurement system includes a tubular suspended downhole, the tubular having an outer surface and a flowbore extending therethrough, the flowbore conveying a fluid, a first recess formed in the outer surface of the tubular, a first detection system mounted in the first recess, a second recess formed in the outer surface of the tubular, and a second detection system mounted in the second recess. The second recess is offset relative to the first recess by at least one of an axial distance and a circumferential distance. The first detection system is operable to measure a portion of the data, and the second detection system operable to measure another portion of the data.

Downhole clock method and system

Providing a local response to a local condition in an oil well

A method and apparatus for provid-ing a local response to a local condition in an oil well are disclosed. A sensor is provided to detect a lo-cal condition in a drill string. A controllable element is provided to modulate energy in the drill string. A controller is coupled to the sensor and to the control-lable element. The controller receives a signal from the sensor, the signal indicating the presence of said local condition, processes the signal to determine a lo-cal energy modulation in the drill string to modify said local condition, and sends a signal to the controllable element to cause the determined local energy modu-lation.

Downhole instrument calibration during formation survey

A downhole sensor calibration apparatus includes a rotational or gimbaling mechanism for guiding a sensing axis of an orientation responsive sensor through a three-dimensional orbit about three orthogonal axes. A method includes using measurements taken over the three-dimensional orbit to calibrate the sensor and determine other characteristics of the sensor or tool.

Method and apparatus for nuclear magnetic resonance measuring while drilling

A method for manufacturing NMR measurement-while-drilling tool having the mechanical strength and measurement sensitivity to perform NMR measurements of an earth formation while drilling a borehole, and a method and apparatus for monitoring the motion of the measuring tool in order to take this motion into account when processing NMR signals from the borehole. The tool has a permanent magnet with a magnetic field direction substantially perpendicular to the axis of the borehole, a steel collar of a non-magnetic material surrounding the magnet, antenna positioned outside the collar, and a soft magnetic material positioned in a predetermined relationship with the collar and the magnet that helps to shape the magnetic field of the tool. Due to the non-magnetic collar, the tool can withstand the extreme conditions in the borehole environment while the borehole is being drilled. Motion management apparatus and method are employed to identify time periods when the NMR measurements can be taken without the accuracy of the measurement being affected by the motion of the tool or its spatial orientation.

Surface real-time processing of downhole data

A method and apparatus for controlling oil well drilling equipment is disclosed. One or more sensors are distributed in the oil well drilling equipment. Each sensor produces a signal. A surface processor coupled to the one or more sensors via a high speed communications medium receives the signals from the one or more sensors via the high speed communications medium. The surface processor is situated on or near the earth's surface. The surface processor includes a program to process the received signals and to produce one or more control signals. The system includes one or more controllable elements distributed in the oil well drilling equipment. The one or more controllable elements respond to the one or more control signals.

Method and apparatus for measuring nuclear magnetic resonance during drilling

Drilling with a muscular drill string

A method and apparatus for providing a local response to a local condition in an oil well are disclosed. A sensor is provided to detect a local condition in a drill string. A controllable element is provided to modulate energy in the drill string. A controller is coupled to the sensor and to the controllable element. The controller receives a signal from the sensor, the signal indicating the presence of said local condition, processes the signal to determine a local energy modulation in the drill string to modify said local condition, and sends a signal to the controllable element to cause the determined local energy modulation.

Rotating systems associated with drill pipe

System for controlling oil well drill dynamics

A system is provided to control oil well drilling dynamics. The system includes a plurality of downhole sensor modules, which, when distributed along and coupled to a first portion of a drill string detect a lumped parameter of a second portion of the drill string. Each downhole sensor module produces a sensor signal. The system further includes one or more controllable element modules, which, when distributed along and coupled to a third portion of the drill string affect the lumped parameter of the second portion of the drill string, each controllable element module being responsive to a controllable element signal.

Surface real-time processing of downhole data

A method and apparatus for controlling oil well drilling equipment is disclosed. One or more sensors are distributed in the oil well drilling equipment. Each sensor produces a signal. A surface processor is coupled to the one or more sensors via high-speed communications medium. The surface processor is situated on or near the earth's surface. The surface processor includes a program to process the received signals and to produce one or more control signals. The system includes one or more controllable elements distributed in the oil well drilling equipment. The one or more controllable elements respond to the one or more control signals.

Borehole marking devices and methods

To reduce the surveying error in a wellbore, the creation of several reference points within a borehole is carried out by physically placing borehole markers in the borehole casing, the borehole wall or in the formation itself, and providing an accurate reference of the marker location by either storing information specific to the borehole markers inside or on the marker itself, or assigning an identification number to the marker and storing the information relating to that identification number remotely in a database. The borehole markers may contain an electronic module which includes a microcircuit, a transponder dedicated to the transmission and reception of data to/from a detector placed on a wireline tool, a drill string or a coiled tubing. The detectors may have an additional role of interrogation the electronic modules.

Methods and apparatus for measuring formation properties

This application relates to various methods and apparatus for rapidly obtaining accurate formation property data from a drilled earthen borehole. Quickly obtaining accurate formation property data, including formation fluid pressure, is vital to beneficially describing the various formations being intersected. For example, methods are disclosed for collecting numerous property values with a minimum of downhole tools, correcting and calibrating downhole measurements and sensors, and developing complete formation predictors and models by acquiring a diverse set of direct formation measurements, such as formation fluid pressure and temperature. Also disclosed are various methods of using of accurately and quickly obtained formation property data.

Method and system for downhole clock having compensation

A downhole crystal-based clock that is substantially insensitive to the factors that cause frequency deviation. The clock may be maintained at a predetermined temperature using a temperature sensing device and a heating device, where the predetermined temperature corresponds to the temperature at which the crystal experiences only slight frequency deviation as a function of temperature. A microprocessor may monitor the clock and compensate for long-term aging effects of the crystal according to a predetermined algorithm. The predetermined algorithm may represent long-term aging effects of the crystal which were derived by comparing the crystal clock to a more accurate clock (e.g., an atomic clock) prior to placing the clock downhole. In this manner, the crystal-based clock may be substantially free from the factors that cause frequency, and therefore time variations.

Downhole instrument calibration during formation survey

A DOWNHOLE SENSOR CALIBRATION APPARATUS (10) INCLUDES A ROTATIONAL OR GIMBALING MECHANISM FOR GUIDING A SENSING AXIS (115) OF AN ORIENTATION RESPONSIVE SENSOR (114) THROUGH A THREE- DIMENSIONAL ORBIT ABOUT THREE ORTHOGONAL AXES. A METHOD INCLUDES USING MEASUREMENTS TAKEN OVER THE THREE-DIMENSIONAL ORBIT TO CALIBRATE THE SENSOR AND DETERMINE OTHER CHARACTERISTICS OF THE SENSOR OR TOOL.

Method and apparatus for nuclear magnetic resonance measuring while drilling

A method for manufacturing NMR measurement-while-drilling tool having the mechanical strength and measurement sensitivity to perform NMR measurements of an earth formation while drilling a borehole, and a method and apparatus for monitoring the motion of the measuring tool in order to take this motion into account when processing NMR signals from the borehole. The tool has a permanent magnet with a magnetic field direction substantially perpendicular to the axis of the borehole, a steel collar of a non-magnetic material surrounding the magnet, antenna positioned outside the collar, and a soft magnetic material positioned in a predetermined relationship with the collar and the magnet that helps to shape the magnetic field of the tool. Due to the non-magnetic collar, the tool can withstand the extreme conditions in the borehole environment while the borehole is being drilled. Motion management apparatus and method are employed to identify time periods when the NMR measurements can be taken without the accuracy of the measurement being affected by the motion of the tool or its spatial orientation.

Magnetostrictive power supply for bottom hole assembly with rotation-resistant housing

A power supply includes a rotor having an undulated surface ( 658, 858, 958, 10, 58 ) and a magnetostrictive material disposed adjacent to the undulated surface. The undulated surface alternatingly compresses the magnetostrictive material as the rotor rotates, inducing an electric current in a conductor coupled to the magnetostrictive material.

drilling rig for use in drilling a wellbore and method for drilling a wellbore with a drillhole

sistema para a perfuração de um furo de poço com uma broca de perfuração e com um tubo de perfuração com fio portando potência elétrica a partir da superfície, coluna de perfuração para uso na perfuração de um furo de poço e método para a perfuração de um furo de poço com uma coluna de perfuração. métodos e aparelhos para a perfuração de um furo de poço são mostrados. um motor elétrico acoplado de forma elétrica e de forma mecânica a um tubo de perfuração com fio é provido. o motor elétrico se acopla a um eixo que gira, quando a potência é suprida para o motor elétrico. o eixo é acoplável a uma broca de perfuração. o tubo de perfuração com fio transfere eletricidade para o motor elétrico a partir da superfície. a operação do motor elétrico gira o eixo. a broca de perfuração desgasta o terreno para a formação do furo de poço no terreno. system for drilling a wellbore with a drill bit and a corded drill pipe carrying electrical power from the surface, drill string for use in drilling a wellbore and method for drilling a wellbore well with a drill string. Methods and apparatus for drilling a wellbore are shown. an electrically and electrically coupled electric motor to a wired drill pipe is provided. The electric motor engages a rotating shaft when power is supplied to the electric motor. The shaft is couplable to a drill bit. The wired drill pipe transfers electricity to the electric motor from the surface. Electric motor operation rotates the shaft. The drill bit wears the ground for the formation of the wellbore in the ground.

Evaluating wellbore telemetry systems

Evaluating wellbore telemetry systems. Multiple evaluation signals are serially transmitted to multiple serially connected components of a wellbore telemetry system disposed in a wellbore. Each component is addressable by a respective one of the multiple evaluation signals. In response to serially transmitting the multiple evaluation signals, multiple communication links to the multiple components are evaluated based on a respective multiple responses to the multiple evaluation signals.

Calibration of borehole instrument during formation mapping

En apparatur for sensorkalibrering i borehull inkluderer en omdreinings- eller kardang-opphengingsmekanisme for å styre en avlesningsakse for en orienteringsresponsiv sensor gjennom en tredimensjonal bane om tre ortogonale akser. En fremgangsmåte inkluderer å bruke målinger tatt over det tredimensjonale kretsløpet for å kalibrere sensoren og å fastslå andre karakteristikker for sensoren eller verktøyet. A borehole sensor calibration apparatus includes a pivot or velocity suspension mechanism for guiding a reading axis of an orientation responsive sensor through a three-dimensional path about three orthogonal axes. One method includes using measurements taken over the three-dimensional circuit to calibrate the sensor and to determine other characteristics of the sensor or tool.

METHOD FOR REPORTING DATA IN A WELL HOLE

Drilling method

Undesirable and non-productive dynamic behavior of the drill string can detract from rapid, cost-efficient and safe drilling of a borehole. The present invention relates to a method of drilling including the step of exciting a standing wave in a drill string. The latter step allows one to address perturbations or standing waves evolving from the drilling process, which otherwise might be detrimental.

Surface real-time processing of downhole data

A method and apparatus for controlling oil well drilling equipment is disclosed. One or more sensors (150, 180) are distributed in the oil well drilling equipment (140). Each sensor produces a signal. A surface processor (185) is coupled to the one or more sensors (150, 180) via high-speed communications medium (190). The surface processor (185) is situated on or near the earth's surface. The surface processor (185) includes a program to process the received signals and to produce one or more control signals. The system includes one or more controllable elements (170, 175) distributed in the oil well drilling equipment (140). The one or more controllable elements (170, 175) respond to the one or more control signals.

Rotating systems associated with drill pipe for conveying electrical power to downhole systems

Methods and apparatuses for drilling a borehole are disclosed. An electric motor electrically and mechanically coupled to a wired drill pipe is provided. The electric motor couples to a shaft that rotates when power is supplied to the electric motor. The shaft is couplable to a drill bit. The wired drill pipe transfers electricity to the electric motor from the surface. Operation of the electric motor rotates the shaft. The drill bit wears away earth to form the borehole in the earth.

Apparatus and method for detecting pressure signals

An apparatus for detecting data in a fluid pressure signal in a conduit comprises an optical fiber loop comprises a measurement section and a delay section wherein the measurement section is disposed substantially circumferentially around at least a portion of the conduit, and wherein the measurement section changes length in response to the fluid pressure signal in the conduit. A light source injects a first optical signal in a first direction into the measurement section and a second optical signal in a second direction opposite the first direction into the delay section. An optical detector senses an interference phase shift between the first optical signal and the second optical signal and outputs a first signal related thereto.

Rotating systems associated with drill pipe for conveying electrical power to downhole systems

Methods and apparatuses for drilling a borehole are disclosed. An electric motor electrically and mechanically coupled to a wired drill pipe is provided. The electric motor couples to a shaft that rotates when power is supplied to the electric motor. The shaft is couplable to a drill bit. The wired drill pipe transfers electricity to the electric motor from the surface. Operation of the electric motor rotates the shaft. The drill bit wears away earth to form the borehole in the earth.

Hydraulic pump with solid-state actuator

A hydraulic pump includes a port and a piston assembly fluidically coupled to the port. The piston assembly includes a piston and a solid-state actuator, where a shape change of the solid-state actuator is induced when a field is applied to the solid-state actuator, and where alternating shape changes of the solid-state actuator provide reciprocating movement to the piston.

Τηλεμετρια παλμων λασπης

Τηλεμετρία παλμών λάσπης. Οι διάφορες υλοποιήσεις αφορούν μεθόδους και συστήματα κωδικοποίησης δεδομένων σε ένα σύστημα τηλεμετρίας παλμών λάσπης, όπου τουλάχιστον ένα τμήμα των δεδομένων κωδικοποιείται στον χρόνο μεταξύ μεταπτώσεων πίεσης. Επιπλέον, οι διάφορες υλοποιήσεις αφορούν μεθόδους ανίχνευσης και συστήματα που ανιχνεύουν τις μεταπτώσεις πίεσης στην επιφάνεια.

Formation treatment using electromagnetic radiation

Formation treatment using electromagnetic radiation

A method of treating a subterranean formation includes injecting a magnetically permeable material into the formation and energizing the magnetically permeable material using electromagnetic radiation. The magnetically permeable material reacts to the electromagnetic radiation by producing heat. In some embodiments, a fracturing fluid is made magnetically permeable, injected into the formation to fracture the formation, and heated in response to electromagnetic radiation applied to the magnetically permeable material. In some embodiments, electromagnetically heated material is caused to explode. In some embodiments, the magnetically permeable material is tracked or monitored for fluid or fracture propagation. A system includes a fluid treatment tool (100, 200) disposed on a tubing string (118, 208, 318, 518) for injecting magnetically permeable material and an electromagnetic wave generator (300, 400, 500, 602, 702) disposed on the tubing string proximate the fluid treatment apparatus for applying electromagnetic radiation to the magnetically permeable material.

Power production in a completed well using magnetostrictive materials

A device for generating electrical energy from mechanical motion includes a magnetostrictive generator configured to be mechanically coupled to a power conveyance path in a well bore. The power conveyance path is configured to experience an axial force change, and the magnetostrictive generator includes at least one magnetostrictive element that experiences a corresponding force change that results in a change in magnetic permeability in the at least one magnetostrictive element resulting, and is configured to experience a change in magnetic flux in a least one component that is electromagnetically coupled to at least one conductive coil, and the conductive coil is configured to generate electricity due to these magnetic flux changes.