Advanced Upstream Ltd.

Baker Hughes, a Ge Compnay, LLC

Jeyhun Najafov

Tom Watkins

Henryk Kozlow

Ratish Suhas Kadam

Silviu Livescu

Thomas J Watkins

Timothy T Ramsey

Bo Wu

William A Aitken

Stuart J Murphy

Ken P Dobkins

William B Oliver

Thomas T Watkins

A device for wellbore operations is configured to self-determine its downhole location in a wellbore in real-time and to self-activate upon arrival at a preselected target location. The device determines its downhole location based on magnetic field and/or magnetic flux signals provided by an onboard three-axis magnetometer. The device optionally comprises one or more magnets. The magnetometer detects changes in magnetic field and/or magnetic flux caused by the device's proximity to or passage through various features in the wellbore. The device can self-activate to deploy an engagement mechanism to engage a target tool downhole from the target location. The engagement mechanism comprises a seal supported by two expandable support rings, each having a respective elliptical face for engagement with the elliptical face of the other support ring.

Devices, systems, and methods for selectively engaging downhole tool for wellbore operations

A method for transporting an untethered wellbore completion apparatus to an outlet of a transport system that is operably coupled to and in fluid communication with a wellhead, from a location remote from the wellhead is disclosed. In some embodiments, the transporting includes propelling the object through a conductor of the transport system by moving a gaseous fluid through the conductor. In some embodiments, the object is a dart for use in a wellbore completion operation.

Pneumatic transport system and method for wellbore operations

A device for wellbore operations is configured to self-determine its downhole location in a wellbore in real-time and to self-activate upon arrival at a preselected target location. In embodiments, the device is configured to self-determine its direction of travel and self-deactivates if the device determines that it is not travelling in the downhole direction. In embodiments, the device has a flowback valve that blocks fluid flow therethrough when the device is inactivated but permits fluid flow through the device to exit at the device's trailing end when the device is activated. In embodiments, at least a portion of the device is dissolvable in the presence of wellbore fluids. In embodiments, at least a portion of the device is coated with a protective coating to shield the device from treatment fluids. A downhole tool having a pass-through constriction configured to be overcome by the device is also disclosed.

A port sub comprises one or more standard flow ports, each having a low-pressure port assembly positioned therein to, and at least one control flow port having a high-pressure port assembly positioned therein. The low-pressure port assembly comprises an inner layer having a first rupture pressure and an outer layer configured to remain intact upon the rupturing of the inner layer. The high-pressure port assembly comprises an inner layer having a second rupture pressure that is greater than the first rupture pressure. The high-pressure port assembly is configured to be broken through upon the rupturing of its inner layer to allow fluid flow through the at least one control flow port, thereby allowing a dissolve fluid to flow therethrough to facilitate the disintegration of the outer layer of the low-pressure port assembly to open the one or more standard flow ports.

Port sub with delayed opening sequence

A method and related system for transporting an object to an outlet of a transport system operably coupled to an in fluid communication with a wellhead, from a location at a distance to the wellhead are disclosed. In some embodiments, the transporting includes propelling the objection through a pipeline of the transport system by moving a gas in the pipeline. In some embodiments, the object is a dart for use in a wellbore completion operation.

A dart for effecting wellbore operations has an inactivated position and an activated position wherein the exterior profile of the dart is changed when the dart is activated. The change in profile may be achieved by moving (for example, rotating) a portion of the dart relative to the remaining portion. When inactivated, the exterior profile allows the dart to pass freely through a valve. When activated, the dart cannot pass through the valve because the changed exterior profile is caught by the interior profile of the valve. Once caught, the dart creates a seal to open the valve when fluid pressure above the seal is increased. The dart can thus be used in multiple stage applications with valves having seats of the same size so that the dart can be selectively activated to engage a desired valve seat.

Dart with changeable exterior profile

A telemetry system for a resource exploration and recovery system including a tubular defining a flow bore, and a superconductor wire disposed within the flow bore. A resource exploration and recovery system including a first system, a second system fluidically connected to the first system, and a telemetry system operatively connected to the first system extending into the second system, the telemetry system including a tubular defining a flow bore, and a superconductor wire disposed within the flow bore.

Telemetry system including a super conductor for a resource exploration and recovery system

Systems and methods for reducing unwanted water and/or gas intrusion into a hydrocarbon production wellbore. The system includes a treatment injection tool for injecting a treatment agent into portions of the formation surrounding the wellbore and a tunneling tool for forming one or more tunnels within the formation. Sensors provide real-time information about wellbore parameters during treatment so that wellbore analysis can be conducted.

Treatment methods for water or gas reduction in hydrocarbon production wells

An injector control system for a coiled tubing unit includes a programmable logic controller arranged to receive a signal related to sensed parameters of a coiled tubing injection operation; a traction pressure control hydraulic circuit operable to adjust hydraulic pressure provided to at least one traction cylinder in a coiled tubing injection head; a motor pressure control hydraulic circuit operable to adjust hydraulic pressure provided to at least one motor of the coiled tubing injection head; and at least one of the traction pressure control hydraulic circuit and the motor pressure control hydraulic circuit including a proportional control valve in receipt of a variable electrical signal from the programmable logic controller. The programmable logic controller adjusts the signal delivered to the proportional control valve throughout the coiled tubing injection operation as dictated by the sensed parameters.

Intelligent injector control system, coiled tubing unit having the same, and method

A milling assembly for use in milling away an object in a wellbore. A milling bottom hole assembly is run in on a Telecoil&#xae; running string and includes a rechargeable power section which is recharged via tube-wire in the running string. The milling bottom hole assembly also includes a sensor section which measures tension, compression and torque experienced by the running string during milling.

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Calgary, Canada

Jeyhun Najafov