Weatherford/lamb, Inc.

Triple J Technologies, LLC

Universal Wellhead Services Holdings, LLC

Other

Vault Pressure Control LLC

Jack Allen

James Otis Miller

Jimmy Duane Streety

Tuong Thanh Le

Joe Noske

David Graham Hosie

Ram Kumar Bansal

David Pavel

Michael J Lynch

Allen Richard Young

Kenneth Edmund Rozek

Kenneth Michael Nero

Mark Christopher Glaser

Ralph Anthony Alvarez

Gerald M Ferguson

A hanger assembly has at least one elongated channel disposed on the outer surface of the hanger assembly. An alignment/anti-rotation tab member is moveably disposed within each elongated channel and can selectively alternate between a first retracted configuration and a second extended configuration. In the second extended configuration, each alignment/anti-rotation tab member can be received within a mating channel along the inner surface of the central through bore of the wellhead. Each extended alignment/anti-rotation tab member can engage against a mating recess or channel in order to align and orient the hanger assembly within the central through bore of the wellhead (permitting orientation and alignment of ports in the hanger assembly and the surrounding wellhead), while also preventing rotation of the hanger assembly relative to the wellhead.

Hanger assembly with alignment/anti-rotation system

A connector assembly that selectively connects to a wellhead housing having a clamp type hub. The connector assembly utilizes a selectively energized clamp type connector and an internal replaceable seal assembly; the connector has clamp segments that selectively engage and secure against the clamp hub of the wellhead housing. As the connector assembly engages the wellhead housing, the internal replaceable seal member engages with the wellhead hub (and typically a seal ring thereof) to form a fluid pressure seal.

Wellhead connector assembly with replaceable sealing member

In various implementations, a hydraulic fracturing piping system may include one or more rotatable elbows to connect other components of the hydraulic fracturing piping system. Using rotatable elbows may facilitate connections in the hydraulic fracturing piping system. For example, when using a rotatable elbow, in the assembly of the system, the rotatable elbow may be capable of rotating to different positions to facilitate alignment of the hydraulic fracturing manifold and hydraulic fracturing stack (e.g., christmas tree), when the hydraulic fracturing manifold and the hydraulic fracturing stack are not in alignment. In some implementations, the elbow may include an internal radial transition (e.g., of approximately 90 degrees) to control the media being injected into the wellbore. The internal radial transition of the elbow may create a more uniform media flow and/or less turbulence, which may significantly reduce erosion of the inner surfaces the bore of the elbow.

System for connecting piping systems for hydraulic fracturing of oil and gas wells

A cage for a choke valve assembly and method for using the same is provided. The cage includes one or more teardrop shaped orifices for the manipulation of fluid flow through the choke valve assembly.

Oilfield choke with teardrop shaped flow orifices

A method for removing a tubular from a wellbore can include repeatedly and sequentially using an upper gripping member of an upper section and a lower gripping member of a lower section to hydraulically grip the tubular, while repeatedly and sequentially extending and retracting the upper section relative to the lower section to raise the tubular from the wellbore to a predetermined height. At least one lifting hole can be formed in the tubular, and a lifting member can be installed in each lifting hole. A hoist can be connected with each lifting member. The tubular can be cut using a saw and removed from the wellbore using the hoist.

Method for lifting a tubular from a well

A tubular lift safety system can include a wellbore tubular removal system for removing tubulars from wellbores, which can have an upper section movable relative to a lower section. The upper section and the lower section can both have gripping members for gripping and releasing the tubulars while the upper section is moved relative to the lower section; thereby removing the tubulars from the wellbore. The upper section can have cutting devices for forming lifting holes and a saw for cutting the tubulars. A fluid source can control extension and retraction of the upper section relative to the lower section, operation of the gripping members, and operation of the saw. A remote control can monitor pressure from the fluid source.

System for removing a tubular

A wellbore tubular lift safety system and tubular lifting apparatus for removing tubulars can include a lower section with a lower base plate hole, sliding rods, and a lower gripping member. An upper section can have an upper base plate hole, a saw mounting plate hole, an upper gripping member, and cylinder barrels. The sliding rods can be engaged within the cylinder barrels, and can be moved therein for extending and retracting the upper section. The apparatus can be positioned over the wellbore in a retracted position to align with the tubular. The tubular can be lifted out of the wellbore by gripping the tubular using the gripping members, and extending and retracting the upper section. The apparatus can form lifting holes in the tubular, install lifting members in the lifting holes, saw the tubular, and allow the cut tubular to be lifted via a hoist.

Tubular lifting apparatus

Methods and apparatus for communicating between surface equipment and downhole equipment. One embodiment of the invention provides a wellhead assembly that allows electrical power and signals to pass into and out of the well during drilling operations, without removing the valve structure above the wellhead. Another embodiment of the invention provides an electromagnetic casing antenna system for two-way communication with downhole tools. Another embodiment of the invention provides an antenna module for a resistivity sub that effectively controls and seals the primary/secondary interface gap.

Apparatus for wellbore communication

A method and apparatus for drilling and completing multiple wellbores from a single drilling rig and from within a single wellhead is provided. In one embodiment, a template is disposed at a predetermined location downhole within a casing. In one aspect, a first casing string is lowered with the template to the predetermined location and disposed within a first wellbore. A second wellbore may be drilled through a bore in the template. A second casing string may then be lowered through the bore into the second wellbore. In another embodiment, at least two wellbores are drilled and completed from a surface casing having a crossover portion.

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Porter, TX, United States of America

Jack Allen