Dril-quip, Inc.

Bruce Joseph Witwer

Blake T DeBerry

Morris B Wade

John Edward Nelson

Mark A Manning

Gregory Dale Williams

Daniel J McLaughlin

James R Bower

Justin Edward Morse

Larry E Reimert

Andrew J Grohmann

Oscar Maldonado

Systems and methods for coupling a platform to a subsea wellhead are provided. The systems may include a riser extending between the platform and the subsea wellhead. The systems may further include an inner drilling riser tie-back connector ('ITBC') coupled to an inner riser and having an outer body and an inner body. The inner body is at least partially disposed within the outer body, and the inner body is translatable along a longitudinal axis of the ITBC between a first unlocked position and a second locked position. The systems may additionally include a locking mechanism for the ITBC.

Inner drilling riser tie-back internal connector

A high capacity universal connector for use in connecting tubular members and a method for sealing the tubular members is provided. First and second tubular members are provided which each have ends that are brought into face-to-face engagement by a connector. A metal sealing element seals against conical surfaces at the ends of the first and second tubular members and enables the entire surface of the end of one tubular member to be bought into engagement with the surface of the end of the other tubular member so as to improve the bending and compression capacity of the assembly comprising the tubular members and the metal sealing element. A metal sealing ring for use in this assembly is also provided, along with a gasket retention assembly.

High capacity universal connector

Hands free gasket retention mechanism

A subsea production system and method for installing the same are provided. The subsea production system includes a high pressure subsea wellhead, a tubing hanger landed proximate the wellhead, a production tree disposed above the wellhead downstream of the tubing hanger, a riser, a subsea flowline system coupled between the production tree and the riser, at least one barrier located downstream of the tubing hanger, and a secondary barrier valve disposed within the tubing hanger or in line with and upstream of the tubing hanger. The at least one barrier provides a pressure barrier that controls pressure of fluid flowing from components of the subsea production system located upstream of the barrier to components of the subsea production system located downstream of the barrier, and the secondary barrier valve is remotely actuable between a closed position and an open position.

Subsea system and method for high pressure high temperature wells

In accordance with the present disclosure, a full top-to-bottom subsea system and method used to drill, complete, produce, and perform interventions on HPHT subsea wells is provided. The disclosed systems and methods involve the use of a controlled multiple barrier system, such as a high integrity pipeline protection system (HIPPS), incorporated into the subsea system to divide the system into two sections. The sections on either side of the barrier may be rated for different pressures, temperatures, and/or flow rates. For example, the first section (upstream of the barrier) is rated for operating at pressures/temperatures/flow rates up to a first (higher) threshold. The second section (downstream of the barrier) is rated for operating at pressures/temperatures/flow rates up to a second (lower) threshold. The disclosed subsea production system methodology, which uses barriers to divide the system components between two pressure ratings, may allow for enhanced development of HPHT reservoirs.

An improved anti-rotation device for preventing rotation of two joined tubular members of a connector assembly is provided. The connector assembly includes a first threaded portion connected to a second threaded portion. The anti-rotation device includes at least one self-tapping screw installed in an associated threaded bore formed in and tangential to a flange of the second threaded portion. When installed, the at least one self-tapping screw engages a shoulder of the first threaded portion. A partial thread is formed in the shoulder of the first threaded portion by the at least one self-tapping screw, which forms a shear-resistive force that prevents rotation of the first threaded portion relative to the second threaded portion, and thus prevents rotation of one tubular member relative to the other.

Anti-rotation device for connector assembly and method

An apparatus and methods for installing and selectively retrieving a casing hanger locking device within a wellhead system during the bit run and retrieval operations are provided. An embodiment is an apparatus comprising: a bit sub comprising a tong neck, a cylindrical portion below the tong neck, and at least one stabilizing fin below the cylindrical section, wherein the at least one stabilizing fin comprises a keyway; a casing hanger locking device comprising an annular structure and an expandable ring disposed around an upper portion of the annular structure, the casing hanger locking device disposed around the bit sub; an actuation sleeve that engages with the casing hanger locking device; and a selective retrieval collar comprising a segmented retrieval ring, wherein the selective retrieval collar is attached to the bit sub, the actuation sleeve, and the casing hanger locking device.

Method and apparatus for bit run and retrieved casing hanger locking device

In accordance with embodiments of the present disclosure, a seal assembly for sealing and locking a casing hanger to a wellhead includes a lower seal body, an upper seal body connected to the lower seal body, an inner lock ring disposed between the upper seal body and the lower seal body, an external lock ring engaging the upper seal body, and an energizing ring. The lower seal body is structured and arranged to form a seal with the casing hanger and the wellhead. The upper seal body includes a load portion that overhangs a load shoulder of the casing hanger. At least a portion of the energizing ring is disposed within an inner groove disposed within the upper seal body. The energizing ring locks the inner lock ring into forcible engagement with the casing hanger, and locks the external lock ring into engagement with the wellhead.

Metal to metal annulus seal with enhanced lock-down capacity

A seal assembly () is provided for sealing between an interior surface () on a wellhead () and a tapered exterior surface () on a hanger (). A unitary seal body () includes an upper portion for engagement with a force tool and a lower portion for sealing with the wellhead and the hanger. A first locking ring () is movable radially inward for securing the sealing assembly to the hanger, and a second locking ring () is movable radially outward for securing the seal assembly to the wellhead. An actuation member () including a plurality of downward extending fingers passing through slots in the seal body move downward through a portion of the body to force the first and second locking rings into engagement with the wellhead and the hanger.

Growing community of inventors

Cypress, TX, United States of America

Bruce Joseph Witwer