Saudi Arabian Oil Company

Khaled K Abouelnaaj

Victor Carlos Costa De Oliveira

Mario Augusto Rivas Martinez

Dean S Porter

Bader S Al-Zahrani

Hugo Fernando Osorio Cuellar

Rafael M Pino Rojas

Ossama R Sehsah

Ramon Rodriguez Rico

Rodny Benjamin Masoud Zuleta

A pipe coupling device includes a body configured to connect a first pipe segment to a second pipe segment, a sealing device carried by the body, and an activation unit. The sealing device includes a circumferential element including a first material and a peripheral element connected to an edge of the circumferential element and including a second material that is different from the first material. The activation unit is configured to adjust the sealing device to an activated state in which the sealing device extends radially from the body to form at least a portion of a seal with a pipe that surrounds the body, such that the seal fluidically isolates a first annular region between the first pipe segment and the pipe along a first side of the seal from a second annular region between the second pipe segment and the pipe along a second side of the seal.

Pipe coupling devices for oil and gas applications

A system and a method for reducing annular pressure with a casing annulus pressure release system are described. The casing annulus pressure release system includes a controller, multiple sensors, and a pressure release sub-system disposed a wellbore annulus. The sensors sense wellbore conditions in the annular space and transmit signals representing the sensed wellbore conditions to the controller. The pressure release subsystem releases pressure in the annular space into the wellbore in response to a signal from the controller.

Reducing wellbore annular pressure with a release system

A smart system for circulating LCM can implement a method. While a wellbore is being drilled in a geologic formation, drilling parameters identifying wellbore drilling conditions of a wellbore drilling system drilling the wellbore are received. The wellbore drilling system flows a wellbore drilling fluid including particulates of different size distributions. The particulates operate as LCM to reduce loss of the wellbore drilling fluid in the geologic formation. Size distributions of the particulates in the wellbore drilling fluid flowing through multiple different wellbore fluid flow pathways of the wellbore drilling system are received. The size distributions represent a concentration of the particulates in the wellbore drilling fluid. A release of certain particulates into the wellbore drilling fluid is controlled based, in part, on the received drilling parameters and the received size distributions of the particulates.

Smart system for selection of wellbore drilling fluid loss circulation material

An unbalanced sub-assembly includes a turbine and a shaft coupled to the turbine at a first end of the shaft. The unbalanced sub-assembly is capable of rotating and imparting a vibration to the casing in response to a fluid being passed through the casing. A rupture disc is positioned on one end of the unbalanced sub assembly. The rupture disc is configured to rupture above a specified differential pressure threshold caused by fluid flowing through the vibration assembly. The rupture disc is capable of allowing the fluid to bypass the unbalanced sub assembly when the rupture disc is in a ruptured state. The rupture disc directs fluid through the unbalanced sub assembly when the rupture disc is in an un-ruptured state.

Vibration-induced installation of wellbore casing

A retractable and extendable cone-type reamer is positioned on a drill string. An extension and retraction mechanism is configured to extend and retract the cone-type reamer. A hydraulic power unit is configured to control the extension and retraction mechanism. Sensors are positioned on or within the cone-type reamer. The sensors are configured to detect parameters of the wellbore-type hole opening system. A controller is operatively coupled to the hydraulic power unit and the sensors. The controller is configured to be positioned in a wellbore. The controller is configured to receive signals from the sensors. The signals represent the parameters detected by the sensors. The controller is configured to identify the parameters represented by the signals. The controller is configured to adjust a parameter of a wellbore-type hole opening operation in response to the received signals.

Opening a wellbore with a smart hole-opener

A retractable and extendable roller reamer is positioned on a string. The retractable and extendable roller reamer is configured to support and centralize the string within the wellbore. An extension and retraction mechanism is configured to extend and retract the roller reamer. A hydraulic power unit is configured to control the extension and retraction mechanism. Sensors positioned on or within the roller reamer. The sensors are configured to detect parameters of the well-string stabilizing system. A controller is operatively coupled to the hydraulic power unit and the plurality of sensors. The controller is configured to be positioned in a wellbore. The controller is configured to receive signals from the sensors. The signals represent the parameters detected by the sensors. The controller is configured to identify the parameters represented by the signals. The controller is configured to adjust a well-string stabilizing operation in response to the received signals.

Supporting a string within a wellbore with a smart stabilizer

A drilling jar in an oil and gas drilling operation or fishing operation includes a control unit having one or more transceivers configured to communicate wirelessly with a surface control unit. The control unit is configured to receive an activation signal from the surface control unit, and cause to activate the drilling jar in response to the activation signal. The wireless transceivers may communicate using any wireless communication technology, including but not limited to Wi-Fi, Wi-Fi Direct, and BLE. A method for operating a drilling jar includes receiving, by a control unit comprising one or more transceivers configured to communicate wirelessly with a surface control unit, an activation signal from the surface control unit, and causing to activate the drilling jar in response to the activation signal.

Smart drilling jar

A system for cleaning a wellbore can include a bottom hole assembly that is designed to be run downhole into a wellbore after the wellbore has been drilled and before the wellbore has been cleaned. A control sub-assembly is mounted on and carried by the bottom hole assembly. The control sub-assembly is designed to be positioned within the wellbore. Multiple cleaning sub-assemblies are interchangeably mounted on and carried by the bottom hole assembly. Each cleaning sub-assembly is designed to be positioned within the wellbore. The multiple cleaning sub-assemblies include at least two of the following sub-assemblies: a scraping sub-assembly that scrapes an interior of the wellbore, a brushing sub-assembly that brushes the interior of the wellbore, or a magnetic sub-assembly that magnetically captures debris within the wellbore.

Interchangeable wellbore cleaning modules

Systems and methods for sealing a wellbore are described. The system includes a packing element configured to at least partially seal an uphole portion of a wellbore from a downhole portion of the wellbore. A first annular pressure sensor is positioned uphole of the packing element. The first annular pressure sensor is configured to measure a first pressure within the wellbore uphole of the packing element. A second annular pressure sensor is positioned downhole of the packing element. The second annular pressure sensor is configured to measure a second pressure within the wellbore downhole of the packing element. A control sub-assembly is configured to be positioned within the wellbore. The control sub-assembly is configured to monitor a sealing efficiency of the system by comparing the first pressure and the second pressure.

Systems and methods for sealing a wellbore

An unbalanced sub-assembly is located within the wellbore casing shoe. The unbalanced sub-assembly includes a turbine and a shaft coupled to the turbine at a first end of the shaft. The unbalanced sub-assembly is configured to rotate and to impart a vibration to the casing in response to a fluid being passed through the casing. A rupture disc is positioned on one end of the unbalanced sub assembly. The rupture disc is configured to rupture above a specified differential pressure threshold caused by fluid flowing through the vibration assembly. The rupture disc is configured to allow the fluid to bypass the unbalanced sub assembly when the rupture disc is in a ruptured state. The rupture disc is configured to direct fluid through the unbalanced sub assembly when the rupture disc is in an un-ruptured state.

A stage cementing tool includes a top sub-assembly; a bottom sub-assembly; a housing that connects the top and bottom sub-assembly and includes a bore therethrough from the top sub-assembly to the bottom sub-assembly, the housing including a plurality of ports radially arranged in the housing, each port including a fluid path between an interior radial surface of the housing and an outer radial surface of the housing; at least one sleeve that rides on a portion of the housing; and a controller mounted in the housing and configured to control the sleeve to adjust, based on receipt of a command to the controller from the terranean surface, between a first position such that the sleeve mandrel decouples fluid communication from the bore to an exterior of the housing through the fluid paths and a second position such that the sleeve mandrel fluidly couples the bore with the exterior of the housing through the fluid paths.

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Dhahran, Saudi Arabia

Khaled K Abouelnaaj