Pes Limited

Centergenics, LLC

Chevron U.s.a. Inc.

Other

Baker Hughes Corporation

Welldynamics, Inc.

Production Sciences, Inc.

Napoleon Arizmendi

Brett W Bouldin

Richard Paul Rubbo

Mark Hiroshi Yamasaki

Jeffrey John Lembcke

Henry J Jordan, Jr

Alfred R Curington

Steve Owens

Richard P Rubbo

Timothy Tips

A wellbore casing self-tightening tubular gripping device.

Tapered thread tubular gripping device

A tubular gripping device comprising an outer body, a self-locking mechanism, and a retainer member. The outer body defines an inner tubular cavity having a first inner diameter, a second inner diameter, a first load shoulder, and a second load shoulder. The first load shoulder tapers the first inner diameter down to second inner diameter at the second load shoulder. The second load shoulder acts as a stop at the second inner diameter. The self-locking is mechanism positioned substantially co-axially within the tubular cavity of the outer body and proximate the first inner diameter, the self-locking mechanism having a spring expanded and a spring released position. The retainer member has a first retainer position radially restraining the self-locking mechanism in the spring expanded position and a second retainer position allowing the self-locking mechanism to contract to the spring released position to grip an outer surface of a tubular member.

Tubular gripping device

A lock capable of self-locking onto a tubular and onto another centralizer. The lock collar being of the type used in production strings of tubulars in the oilfield. The lock collar relates to mechanisms such as stop rings for centralizers commonly used in downhole applications to prevent axial and rotational movement of centralizers mounted on the tubing or casing outer surface.

Centralizer and locking collar

A centralizer capable of self-locking onto a tubular. The centralizer being of the type used in production strings of tubulars in the oilfield. The centralizer relates to mechanisms such as stop rings for centralizers commonly used in downhole applications to prevent axial and rotational movement of centralizers mounted on the tubing or casing outer surface.

Locking centralizer

A lock collar for locking a centralizer in place on a tubular of the type used in production strings in the oilfield. The lock collar relates to mechanisms such as stop rings or lock collars commonly used in downhole applications to prevent axial and/or rotational movement of centralizers mounted on the tubing or casing outer surface.

Locking collar

Systems and processes are provided for removing fluid from a subterranean well and enhancing the production of oil and/or gas are herein disclosed. In one embodiment, the system includes an injection conduit, an injection valve, a relief valve, a container, a container valve, a return conduit valve, and a return conduit, all arranged within a subterranean well for removing at least one fluid from the well. The removal of at least one fluid from the well is controlled by the flow of gas into the injection conduit.

Processes and systems for treating oil and gas wells

A casing centralizer which has an annular body having a substantially cylindrical bore extending longitudinally therethrough. The annular body is divided along its axis into two inter-connectable sections, each of which includes fins extending radially therefrom. Each inter-connectable section also includes at least one latch and at least one alignment guide, as well as at least one latch cavity configured for matingly receiving and interlocking with the at least one latch of the other inter-connectable section, and at least one alignment guide cavity configured for matingly receiving and interlocking with the at least one alignment guide of the opposing inter-connectable section. The two inter-connectable sections may then be clamped about a drill pipe for maintaining a centralized position of the drill pipe in a downhole casing.

Insulated tubular clamp

Various embodiments of the present invention disclose enhanced and improved well production tools for increasing the stability of production zones in a wellbore. Various embodiments of the present invention generally relate to apparatuses, systems, and processes for efficiently and effectively isolating zones within a wellbore.

Fracture valve tools and related methods

Blapper valve tools and related methods

A hydraulically set concentric packer with multiple umbilical bypass through the piston. In a described embodiment, a packer for use in a subterranean well includes a piston which displaces to set the packer in the well, and a line extending through the piston. The piston has concentric inner and outer diameters, and is concentric with an inner mandrel and an outer housing of the packer.

Hydraulically set concentric packer with multiple umbilical bypass through the piston

A high pressure connector for engagement with a hydraulic conduit for use in high pressure conditions such as downhole in a wellbore. A housing for receiving a conduit end is attachable to a primary retainer. A primary seal and a second seal are positioned between the primary retainer and the housing to provide redundant sealing capabilities. A secondary retainer holds a third seal against the primary retainer. The third seal provides redundant sealing capability and further provides a secondary gripping connection along the conduit length. The secondary gripping connection provides greater tensile strength and reduces the impact of conduit vibration. A test apparatus can be adapted to test the primary seal and the second and third seals before the connector is installed downhole in the well or other high pressure environment.

High pressure hydraulic line connector

An expandable apparatus for sealing a space downhole in a wellbore. The apparatus has an expandable body having a hollow interior for defining an open flow path. A deformable material within the hollow body interior partially obstructs the flow path when the body is run into the wellbore, and the deformable material is displaceable to expand the body into the downhole space and to open the body flow path. Such material can be displaced with a setting tool or with mechanical movement of the body components. A second body section can be moved relative to a first body section to displace the deformable material from the body interior. The second body section can initially be discontinuous with the first body section to permit installation through narrow wellbore spaces and can be connected downhole to create a unitary body structure.

High expansion downhole packer

A high expansion slip system for anchoring a tool to a downhole wellbore surface. A slip is initially retained within the interior volume of a tool body for installation downhole in the wellbore. The slip has an inclined surface which moves the slip radially outwardly when the slip is move axially along a longitudinal axis through the tool body. Two opposing slips can be operated to center the tool body within the wellbore, and the setting of the two slips can be synchronized to control the tool body position and setting force on each slip. After the slips have been moved from the interior space to engage the wellbore surface, the hollow interior space within the tool body is unobstructed to open an unobstructed flow path for passage of fluids or well tools.

High expansion slip system

A flow control apparatus and associated methods of using provide enhanced longevity and reliability without requiring complex mechanisms. In a described embodiment, a choke for use within a subterranean well has a choke member set which may be opened by manipulation of an inner tubular cage. The inner cage is displaced from within an outer sleeve, which restricts fluid flow through ports formed through a sidewall portion of the inner cage. As the inner cage is progressively withdrawn from within the sleeve, the fluid flow through the ports is decreasingly restricted by the sleeve.

Growing community of inventors

Magnolia, TX, United States of America

Napoleon Arizmendi