Saudi Arabian Oil Company

Oladele Owoeye

Jasem Moyaibed

Peter Ido Egbe

Ayodeji Abegunde

Fauzia Rahman Eko Waluyo

Bryan Hall-Thompson

Olaoluwa S Salako

Abdulrahman Nutaifi

Ghadeer A Alrumaih

Zakaria Al Bu

A well system includes a wellbore, a conductor extended within the wellbore, and a wellhead installation arranged at an opening to the wellbore. The wellhead installation includes a low-pressure surface wellhead housing (LPWH) having opposing upper and lower ends, an extension joint secured to the lower end at an offsite location prior to delivery to the wellbore, an extended casing head housing (ECHH) providing a body having opposing first and second ends and sized to be received within the LPWH, the second end being secured to an uphole end of surface casing at an offsite location prior to delivery to the wellbore, and one or more annulus valves extending through a sidewall of the LPWH to provide fluid communication with a conductor-casing annulus defined between the conductor and the surface casing when the ECHH is received within the LPWH.

Big bore low pressure surface wellhead housing systems

A threaded connection includes a first tubular member having a box end defining an internal thread profile, and a second tubular member having a pin end defining an external thread profile threadably engageable with the internal thread profile of the box end. The external thread profile includes a first section that extends at a first taper angle relative to a longitudinal axis of the threaded connection, a second section extending from the first section at a second taper angle relative to the longitudinal axis, and an intermediate shoulder provided at a transition between the first and second sections and engageable with a corresponding intermediate shoulder provided on the internal thread profile. A cross-sectional area of the pin end increases at the intermediate shoulder.

High torque threaded connections with external upset and multiple seals

Systems and methods include a computer-implemented method for the operation of an intelligent powerslip including interfacing with a powerlock system. Measurements from multiple sensors are monitored using an interface between a powerlock and a powerslip of a well. The measurements measure weights, pressures, and temperatures corresponding to use of the powerslip and a grappling device during operation of the well. The measurements from the multiple sensors are compared to pre-determined tolerances to verify that an appropriate engagement exists between the tubular, powerlock and the powerslip. In response to verifying the appropriate engagement and logic, either one of the grappling device or the powerslip can be released depending on the ongoing operation.

Intelligent powerslip and power lock system for running and retrieving tubulars from a wellbore

An uphole section has a first diameter. A midhole section has a second diameter that is larger than the first diameter. The midhole section is attached to the uphole section prior to installation into a wellbore. A downhole section has a third diameter that is smaller than the second diameter. The downhole section is attached to the midhole section prior to installation into the wellbore.

Producing gas through variable bore production tubing

A pipe assembly includes a first pipe, a second pipe, and a collar. The first pipe has a first external thread and a first annular lip that has a first external seal surface and a first internal annular beveled surface. The second pipe has a second external thread and a second annular lip with a second external seal surface and a second internal annular beveled surface. The collar is threadedly coupled to the first pipe and the second pipe to form a coupling connection. The collar has a first internal thread threadedly coupled to the first external thread and a second internal thread threadedly coupled to the second internal thread. The collar has a bore that contacts the first external seal surface and the second external seal surface to form a metal-to-metal seal that is energized under fluid pressure at the first and second internal annular beveled surfaces.

Threaded and coupled connection

A pipe connection system for use in a well completion system includes an inner connector and an outer connector. The inner connector includes a tapered wall and multiple pin threads arranged along the tapered wall, wherein a pitch between projections formed by the multiple pin threads changes along an axial length of the pin connector. The outer connector is formed complementary to the inner connector along at least a portion of the outer connector.

Pipe connection systems in oil and gas applications

A system and a method for controlling a subsea blowout preventer stack with a subsea well control system having sensors and a well control programmable logic controller. The sensors are coupled to the subsea blowout preventer stack and a subsea blowout preventer control system. The subsea blowout preventer control system operates the subsea blowout preventer stack. The sensors sense a condition of the subsea blowout preventer stack and the subsea blowout preventer control system and transmit a signal representing a value of the condition to the well control programmable logic controller. The well control programmable logic controller receives the signal from the sensors, compares the value to a preset value, and in response to the value greater than or equal to the preset value, and transmits a command signal to the subsea blowout preventer control system to seal a fluid flow through the subsea blowout preventer stack.

Controlling a subsea blowout preventer stack

A corrosion resistant alloy suitable for use as a seamless tubular is described. The corrosion resistant alloy includes 13-15 wt. % chromium, 5-7 wt. % nickel, and 2.5-4.5 wt. % molybdenum. The balance of the corrosion resistant alloy is iron.

High performance alloy for corrosion resistance

A top drive assembly includes a top drive, a casing running tool, and a gear assembly. The top drive is coupled to a rig. The casing running tool is fluidly coupled to and driven by the top drive. The gear assembly engages the top drive and the casing running tool to transmit torque from the top drive to the casing running tool. The gear assembly reverses a direction of torque between the top drive and the casing running tool or changes a rotational speed between the top drive and the casing running tool.

Controlling a casing running tool

A modular reamer shoe for connection to an end of a tubular structure, such as a casing or liner, for deployment in a wellbore includes a body configured for connection to the tubular structure (casing or liner). The body includes a first section and an adjacent second section. The first section is connected to the second section such that torque can be transmitted between the first section and the second section. The first section defines a starter reamer defined by a plurality of first cutting elements and second cutting elements spaced from the first cutting elements. The reamer shoe has a plurality of actuatable blades disposed within the second area of the first section. The plurality of blades moves between extended positions and retracted positions. A nose is connected to the first section of the body. The second section is actuatable and can move in an axial direction so as to move the body, including the nose, in forward/rearward directions.

Modular casing reamer shoe system with jarring capability

A tubular connection includes a tubular joint including a pin with a first pin thread having a first pitch and a second pin thread having a second pitch, and also includes a connector that includes a box with a first box thread having the first pitch and a second box thread having the second pitch. The connection also includes an elastomeric seal ring comprised of a material that swells in the presence of hydrocarbons. Upon make-up of the connection, the first pin thread engages with the first box thread, the second pin thread engages with the second box thread, and the elastomeric seal ring is disposed around the tubular joint between the first pin thread and the second pin thread and forms a metal-to-elastomer seal between the tubular joint and the connector.

Threaded tubular connection

A threaded connection includes a first tubular member having a pin end defining an external thread profile, and a second tubular member having a box end defining an internal thread profile threadably engageable with the external thread profile of the pin end. At least one of the external and internal thread profiles includes a first section that extends at a first taper angle relative to a longitudinal axis of the threaded connection, a second section extending from the first section at a second taper angle relative to the longitudinal axis, and a third section extending from the second section at a third taper angle relative to the longitudinal axis. The second taper angle is greater than each of the first and third taper angles.

High torque threaded connections with triple taper thread profiles

A corrosion resistant alloy, a method for making the corrosion resistant alloy, and a method for using the corrosion resistant alloy are provided. The corrosion resistant alloy includes 13-15 wt. % chromium, 5-7 wt. % nickel, and 2.5-4.5 wt. % molybdenum.

Techniques for operating a tubular running tool system include communicating, using a controller, one or more sensors coupled to a tubular running tool during a tubular running operation; identifying, with the controller, a first input from one or more sensors that is associated with a weight of one or more tubular members suspended from the tubular running tool during the tubular running operation; identifying, with the controller, a second input from the one or more sensors that is associated with a position of the tubular running tool relative to a reference location during the tubular running operation; based on at least one of the first or second inputs, determining, with the controller, an operation for the tubular running tool; and based on the determination, transmitting, with the controller, a signal to an actuator of the tubular running tool to perform the operation of the tubular running tool.

Managing a tubular running system for a wellbore tubular

A casing head support system (CHSS) for a casing head includes a casing head support unit (CHSU) having a tubular body with a support unit top end (SUTE) and a support unit bottom end (SUBE); a first conductor string extension joint coaxially fastened to the SUBE; and an internal load profile machined into an inner circumferential surface of the CHSU. The SUTE forms a coaxial connection with the casing head. The internal load profile supports a corresponding load shoulder on a conductor hanger. The CHSU contains a CHSU top preparation machined into the inner circumferential surface of the support unit. The CHSU top preparation is located at the SUTE. The CHSU top preparation mates with a corresponding casing head support unit running tool (CHRT) bottom preparation.

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Dhahran, Saudi Arabia

Oladele Owoeye