Abstract: This disclosure provides a sensor assembly. The sensor assembly, in one aspect, includes a flange housing, the flange housing including a mating surface for engaging a wellhead and an opposing surface, an interior cavity extending into the flange housing from the mating surface, and an exterior cavity extending into the flange housing from the opposing surface. The sensor assembly, according to this aspect, further includes a connector in sealed engagement with the flange housing proximate the exterior cavity, and a control line extending into the interior cavity through the connector. The sensor assembly, according to this aspect, further includes a sensor coupled to an exposed end of the control line proximate the interior cavity, the control line slidable within the connector, the exterior cavity and the interior cavity to move the sensor between a retracted position and an expanded position to accommodate different thickness wellheads.

Abstract: Systems and method for injection a chemical into a wellbore. A chemical injection system may comprise a first valve, a chemical line, a pilot line, an injection line, and a backflow prevention valve disposable in the injection line. A production fluid recovery system may comprise a chemical injection system, a first valve, a pilot line, an injection line, a backflow prevention valve, a production tree, a wellhead, and production tubing. A method for actuating a valve in a chemical injection system may comprise pushing a fluid into a chemical line, pressurizing a pilot line to open a first valve, pushing the fluid through the first valve, increasing pressure in the pilot line to open a second valve, pushing the fluid through the second valve, pushing the fluid through a chemical line, and injecting fluid into a wellbore from the chemical line.

Abstract: A method and system for determining a position of a linearly translating member. The method may comprise transmitting an excitation into a linearly translating member through one or more couplers from an acoustic device disposed in an outer housing, recording a reflected excitation from the linearly translating member with the acoustic device, and identifying a position of the linearly translating member with respect to the acoustic device. The system may comprise an outer housing, a linearly translating member disposed within the outer housing, an acoustic device disposed in the outer housing and configured to transmit an excitation at various frequencies and various amplitudes and record returned excitation frequencies and amplitudes and time of travel, and an information handling system in communication with the acoustic device.

Abstract: A system is provided for providing power and/or communication to/from a downhole device by inductively coupling a coupling conductor within a receiver to a core conductor of a tubing encased conductor (TEC). The receiver has an elongated housing arranged physically proximate or touching an outer surface of the TEC. A coupling conductor is disposed within the housing, extends substantially parallel to a longitudinal axis of the housing, and further extends longitudinally and in close proximity to a core conductor housed within the TEC when the housing is arranged physically proximate or touching the outer surface of the TEC. This exposes the coupling conductor to a magnetic field formed externally to the TEC to excite a current in the coupling conductor. In one or more embodiments, the receiver further includes a coupling to electrically couple the downhole device to the coupling conductor and deliver the current to the downhole device.

Abstract: An array of sensors provided on the outside of a tubular string for measuring a property within the tubular string. The array of sensors may include a plurality of connected sensors, wherein at least one of the plurality of connected sensors is at least partially encompassed in a shroud. A snorkel line may extend from the shroud, the snorkel line capable of coupling with a sensor port in a tubular of the tubular string. The snorkel line may establish fluid communication between one of the sensors at least partially encompassed in the shroud and a corresponding sensor port of a tubular in the tubular string.

Abstract: This disclosure presents an apparatus to improve the position sensing of a moving mechanism, such as a fluid valve located within a borehole. The apparatus can utilize a light beam or an optical fiber to measure changes in the position sensor. The smaller and lighter apparatus can improve the accuracy of the sensing mechanism. In addition, three systems are presented. The first system utilizes a vibration sensor, such as a MEMS, and an accelerometer to calculate changes in the mechanism position of the moving mechanism. The second system utilizes a radiation source and detector combination, along with a moving radiation shield to provide more accurate position sensing than conventional techniques. In addition, a lens-based system is presented, that when combined with a radiation source, can calculate position information by detecting the diffusion or dispersal of the radiation against a radiation detector.

Abstract: A method includes removing a section of electrical insulation proximate an end of a tubing-encased conductor (TEC) to form an end of electrical insulation that is axially recessed relative to the end of the TEC. The method includes welding an end member to an outer surface of the outer tube at a weld joint that is axially between the end of the TEC and the end of the electrical insulation to protect the electrical insulation from heating damage from welding. The method includes replacing the section of electrical insulation proximate the end of the TEC by inserting a spacer into the end of the TEC between the outer tube and the electrical conductor after welding the end member to the outer surface of the TEC. A tool can be electrically connected to the electrical conductor and the tool can be welded to the end member.

Abstract: This disclosure presents an apparatus to improve the position sensing of a moving mechanism, such as a fluid valve located within a borehole. The apparatus can utilize a light beam or an optical fiber to measure changes in the position sensor. The smaller and lighter apparatus can improve the accuracy of the sensing mechanism. In addition, three systems are presented. The first system utilizes a vibration sensor, such as a MEMS, and an accelerometer to calculate changes in the mechanism position of the moving mechanism. The second system utilizes a radiation source and detector combination, along with a moving radiation shield to provide more accurate position sensing than conventional techniques. In addition, a lens-based system is presented, that when combined with a radiation source, can calculate position information by detecting the diffusion or dispersal of the radiation against a radiation detector.

Abstract: A sensor apparatus for wellbore applications includes an electrical conductor extending within an armored tubular jacket to protect the electrical conductor. The electrical conductor is isolated from wellbore fluids when the sensor is placed in a wellhead flange by redundant seals such that the tubular jacket around the conductor does not provide a leak path to the surrounding subsea or surface environment. To isolate the electrical conductor, a connector housing may be provided that establishes a glass-metal seal or a PEEK-metal seal with the electrical conductor. The connector housing may be welded or otherwise sealed to a Christmas tree flange that connects to the wellhead flange. The welds and seals of the sensor apparatus may be proof tested to ensure their effectiveness before the Christmas tree flange is installed in the subsea or surface environment.

Abstract: A system and method for identifying a position of a sliding sleeve. The system may comprise an outer housing, a sliding sleeve within the outer housing, one or more magnetic switches, and a magnet. A method may comprise closing a switch within a magnetic switch disposed with a magnet, wherein the magnetic switch is disposed downhole, and transmitting an electric current into a first electric branch, wherein the electric current traverses through first electric branch, through the magnetic switch, to a second electric branch, and to a node. The method may further comprise measuring the electric current or voltage at the node and identifying a position of a sliding sleeve in an outer housing from the measurement. The method may further comprise calibrating a linear resistor position sensor assembly based at least in part on the measurement.

Abstract: This disclosure provides a sensor assembly. The sensor assembly, in one aspect, includes a flange housing, the flange housing including a mating surface for engaging a wellhead and an opposing surface, an interior cavity extending into the flange housing from the mating surface, and an exterior cavity extending into the flange housing from the opposing surface. The sensor assembly, according to this aspect, further includes a connector in sealed engagement with the flange housing proximate the exterior cavity, and a control line extending into the interior cavity through the connector. The sensor assembly, according to this aspect, further includes a sensor coupled to an exposed end of the control line proximate the interior cavity, the control line slidable within the connector, the exterior cavity and the interior cavity to move the sensor between a retracted position and an expanded position to accommodate different thickness wellheads.

Abstract: Systems for chemical injection. An example system includes a pilot valve comprising: a hydraulic piston, a poppet, and a biasing device. The system further comprises a jay-selector comprising: a rotatable jay-piston having jay-slots, and a plurality of ports. The system additionally comprises a plurality of flow restrictors.

Abstract: A wellbore communication system includes a section of downhole tubing positionable within a wellbore and a track mechanically coupleable to the section of downhole tubing. The wellbore communication system also includes a downhole communication device and an actuator mechanically coupleable to the downhole communication device and the track. In operation, the actuator is able to move the downhole communication device along the track.

Abstract: An array of sensors provided on the outside of a tubular string for measuring a property within the tubular string. The array of sensors may include a plurality of connected sensors, wherein at least one of the plurality of connected sensors is at least partially encompassed in a shroud. A snorkel line may extend from the shroud, the snorkel line capable of coupling with a sensor port in a tubular of the tubular string. The snorkel line may establish fluid communication between one of the sensors at least partially encompassed in the shroud and a corresponding sensor port of a tubular in the tubular string.

Abstract: A sensor apparatus for wellbore applications includes an electrical conductor extending within an armored tubular jacket to protect the electrical conductor. The electrical conductor is isolated from wellbore fluids when the sensor is placed in a wellhead flange by redundant seals such that the tubular jacket around the conductor does not provide a leak path to the surrounding subsea or surface environment. To isolate the electrical conductor, a connector housing may be provided that establishes a glass-metal seal or a PEEK-metal seal with the electrical conductor. The connector housing may be welded or otherwise sealed to a Christmas tree flange that connects to the wellhead flange. The welds and seals of the sensor apparatus may be proof tested to ensure their effectiveness before the Christmas tree flange is installed in the subsea or surface environment.

Abstract: Embodiments of a debris catcher and a debris catching system are disclosed herein. In one embodiment, a debris catching system comprises a plug and a debris catcher, the debris catcher including at least a debris catching sleeve, a running tool coupled to the debris catching sleeve, the running tool including an uphole end and a downhole end, and further wherein the uphole end of the running tool is configured to slide to engage a downhole end of the debris catching sleeve and form a collection base of the debris catcher; and a coupling rod attached to the uphole end of the running tool, the coupling rod configured to engage a downhole setting device; wherein the plug is removably coupled with the downhole end of the running tool during downhole deployment of the debris catching system.

Abstract: A method and system for determining a position of a linearly translating member. The method may comprise transmitting an excitation into a linearly translating member through one or more couplers from an acoustic device disposed in an outer housing, recording a reflected excitation from the linearly translating member with the acoustic device, and identifying a position of the linearly translating member with respect to the acoustic device. The system may comprise an outer housing, a linearly translating member disposed within the outer housing, an acoustic device disposed in the outer housing and configured to transmit an excitation at various frequencies and various amplitudes and record returned excitation frequencies and amplitudes and time of travel, and an information handling system in communication with the acoustic device.

Abstract: An array of sensors provided on the outside of a tubular string for measuring a property within the tubular string. The array of sensors may include a plurality of connected sensors, wherein at least one of the plurality of connected sensors is at least partially encompassed in a shroud. A snorkel line may extend from the shroud, the snorkel line capable of coupling with a sensor port in a tubular of the tubular string. The snorkel line may establish fluid communication between one of the sensors at least partially encompassed in the shroud and a corresponding sensor port of a tubular in the tubular string.

Abstract: A system and method for identifying a position of a sliding sleeve. The system may comprise an outer housing, a sliding sleeve within the outer housing, one or more magnetic switches, and a magnet. A method may comprise closing a switch within a magnetic switch disposed with a magnet, wherein the magnetic switch is disposed downhole, and transmitting an electric current into a first electric branch, wherein the electric current traverses through first electric branch, through the magnetic switch, to a second electric branch, and to a node. The method may further comprise measuring the electric current or voltage at the node and identifying a position of a sliding sleeve in an outer housing from the measurement. The method may further comprise calibrating a linear resistor position sensor assembly based at least in part on the measurement.

Abstract: A method includes removing a section of electrical insulation proximate an end of a tubing-encased conductor (TEC) to form an end of electrical insulation that is axially recessed relative to the end of the TEC. The method includes welding an end member to an outer surface of the outer tube at a weld joint that is axially between the end of the TEC and the end of the electrical insulation to protect the electrical insulation from heating damage from welding. The method includes replacing the section of electrical insulation proximate the end of the TEC by inserting a spacer into the end of the TEC between the outer tube and the electrical conductor after welding the end member to the outer surface of the TEC. A tool can be electrically connected to the electrical conductor and the tool can be welded to the end member.