Schlumberger Technology Corporation

Cameron International Corporation

Matthew David Givens

Vikas Rakhunde

Christopher Nault

Harold Tenorio

Jon Tyler

Stephen McGuire

Ray Cummins

Nathan Cooper

Justin Blair

Michael W Berckenhoff

Darrin Lynn Yenzer

Michael Mancuso

Nicolas Arteaga

Fadhel Rezgui

Ray Zonoz

Steven Shimonek

Alice Chougnet-Sirapian

John Zahl

Hikmet Andic

Olivier Amsellem

Laura M Gardner

Stephane Hoareau

Mathieu Dauphin

Roger D Williams

Estelle Espinosa

Remi Robutel

A detection system includes a pressure sensor configured to contact an annular elastomer component of an annular BOP, wherein the pressure sensor is configured to generate a first signal indicative of a contact pressure with the annular elastomer component. The detection system also includes a piston stroke sensor configured to generate a second signal indicative of a piston stroke distance. The detection system further includes a controller configured to receive the first signal from the pressure sensor and the second signal from the piston stroke sensor and analyze respective changes in the contact pressure and respective changes in the piston stroke distance to determine a condition of the annular BOP.

Detection systems and methods for an elastomer component

A drilling and production system is provided. In one embodiment, such a system has a plurality of functions that are effectuated at least predominately without hydraulic fluid. The system can be a drilling system having a rig and a subsea stack for performing various drilling functions, in which a majority of the drilling functions are effected electrically without hydraulic control fluid. In another embodiment, the rig is coupled to a subsea wellhead assembly but is not connected so as to provide hydraulic control fluid from the rig to the subsea wellhead assembly to enable drilling functions of the subsea wellhead assembly. Additional systems, devices, and methods are also disclosed.

Electrical drilling and production systems and methods

An accumulator system includes a chamber configured to receive a first fluid, a piston configured to move within the chamber to pressurize and drive the first fluid out of the chamber, a driving shaft coupled to the piston, a screw adapter coupled to the driving shaft, a plurality of anti-rotation shafts, and an electric actuator configured to couple to the screw adapter and to rotate the screw adapter to axially move the driving shaft. The piston includes a body defining a first aperture and a plurality of counterbores. The driving shaft is coupled to the piston via the first aperture. The piston is configured to slide over the plurality of anti-rotation shafts via the plurality of counterbores.

Accumulator system

A rotating control device (RCD) system includes a housing having a bore, a seal element positioned within the housing, a piston assembly supported within the housing and configured to drive the seal element to seal the bore, and a bearing assembly supported within the housing and configured to enable the seal element to rotate relative to the housing. The bearing assembly includes a first bearing section positioned between the housing and the seal element and a second bearing section positioned between a piston of the piston assembly and the seal element. The piston assembly is configured to selectively actuate the seal element into a first configuration, where the seal element extends into the bore and seals with a tubular therein, and a second configuration, where the seal element extends entirely through the bore and seals the bore without a tubular extending therein.

Rotating control device system

A drilling and production system is provided. In one embodiment, such a system has a plurality of functions that are effectuated at least predominately without hydraulic fluid. The system can be a drilling system having a rig () and a subsea stack () for performing various drilling functions, in which a majority of the drilling functions are effected electrically without hydraulic control fluid. In another embodiment, the rig is coupled to a subsea wellhead assembly () but is not connected so as to provide hydraulic control fluid from the rig to the subsea wellhead assembly to enable drilling functions of the subsea wellhead assembly. Additional systems, devices, and methods are also disclosed.

An accumulator system that includes a housing. The housing defines a function chamber and a balance chamber. A piston moves axially within the housing. The piston separates the function chamber from the balance chamber. An electric actuator couples to and drives the piston within the housing to compress and drive a first fluid out of the function chamber.

A double acting accumulator system includes a housing including an actuator housing, a first piston housing coupled to the actuator housing, a second piston housing coupled to the actuator housing, a shaft configured to move axially within the first piston housing and the second piston housing, a first piston coupled to a first end of the shaft, a second piston coupled to a second end of the shaft, an electric actuator configured to couple to and drive the shaft to alternatingly compress fluid with the first piston in the first piston housing and the second piston in the second piston housing to drive fluid out of the respective first piston housing and the second piston housing, and a plurality of anti-rotation shafts configured to block rotation of the shaft.

A drilling riser cable management system includes a plurality of clamping mechanisms pre-installed on riser joints and a robotic arm. The robotic arm has a cable handling mechanism that is configured to securely install the cable on each clamping mechanism without relying on human manipulation of the cable during installation.

Cable management on marine drilling risers

A rotating control device (RCD) system includes a housing having a bore, a seal element positioned within the housing, a piston assembly supported within the housing and configured to drive the seal element to seal the bore, and a bearing assembly supported within the housing and configured to enable the seal element to rotate relative to the housing. The bearing assembly includes a first bearing section positioned between the housing and the seal element and a second bearing section positioned between a piston of the piston assembly and the seal element.

Blowout preventers having bodies with internal choke and kill line pass-through conduits are provided. In one embodiment, a blowout preventer body () includes a drill-through bore () extending through the blowout preventer body and a ram cavity () transverse to the drill-through bore. The blowout preventer body can also include choke and kill line conduits () extending through the blowout preventer body, as well as choke and kill line access branch conduits () extending between the choke and kill line conduits and the drill-through bore. Additional systems, devices, and methods are also disclosed.

Blowout preventer with choke and kill line pass through conduits

Blowout preventers having bodies without flanged necks are provided. In one embodiment, a blowout preventer stack includes first and second blowout preventers having independent and separable main bodies, each including a bore and a ram cavity transverse to the bore. The lower end of the main body of the first blowout preventer is fastened directly to an upper end of the main body of the second blowout preventer without a flanged neck extending the bore between the ram cavities of the first and second blowout preventers. In some instances, the main bodies of the first and second blowout preventers include external connection flanges that extend laterally from ram cavity body portions of the main bodies so as to enable connection of the two main bodies along the sides of the main bodies away from their bores. Additional systems, devices, and methods are also disclosed.

Blowout preventer with wide flange body

The service life of a packer element, an annular BOP, is estimated using one pressure sensor below the elastomer seal or two pressure sensors positioned above and below the elastomer seal. The pressure variations below the elastomer are monitored versus piston position and used to detect elastomer wear with time/pressure cycles. The pressure variations above the elastomer can be used to detect potential leakage, as well as leak characteristics such as leaking rate or leak geometry.

BOP elastomer health monitoring

A system includes a flow restrictor assembly configured to be coupled to an annular structure having a central bore. The flow restrictor assembly includes one or more adjustable segments configured to move relative to the annular structure between a retracted position in which the one or more adjustable segments do not extend into the central bore and an extended position in which the one or more adjustable segments extend into the central bore to reduce a cross-sectional flow area of the central bore by between approximately 5 to 95 percent to restrict fluid flow through the central bore.

Growing community of inventors

Houston, TX, United States of America

Matthew David Givens