Fmc Technologies, Inc.

Fmg Technologies, Inc.

Brian J Baca

Roman Chirko

James L Cook

Jeffrey Partridge

Joseph Shu Yian Liew

Huy LeQuang

Gareth Boyd

Dan Fink

Richard Bridwell

Kevin Kok Sum Lim

Hoa Ngoc Nguyen

Cassandra E Weimer

A casing hanger apparatus includes an upper ring, a lower ring, and a packing element positioned between the upper ring and the lower ring. The packing element has an annular body with a wedge-shaped cross-sectional geometry. Bi-directional pressure intensification (BPI) pins are arranged around the casing hanger in an angularly spaced apart configuration, where the BPI pins extend axially from the upper ring through holes in the packing element to the lower ring. In some casing hanger apparatuses, a bushing member is positioned axially between the upper ring and the lower ring, where the BPI pins also extend axially through the bushing member.

Automatic slip-style casing hanger for use with surface wellheads

A diverter valve which includes a valve body, an inlet, a plurality of outlets, an internal cavity to which the inlet and the outlets are connected, and a valve member which is movably positioned in the cavity. The valve member includes a through bore which is configured to connect the inlet with a corresponding one of the outlets for each of a plurality of operative positions of the valve member. In operation of the diverter valve, the valve member is movable between its operative positions to selectively connect the inlet with any one of the outlets.

Frac transfer diverter valve

A tubing hanger assembly including an outer hanger body () lands on a load shoulder () of a tubing head. Additionally, an inner hanger body () having at least one inner hanger groove () moves vertically up and down with respect to the outer hanger body and engages at least one downhole device. A first latch ring () expands into a groove () of the tubing head to lock the outer hanger body in position and a sleeve () with a plurality of grooves () is disposed between the outer hanger body and the inner hanger body of the tubing hanger assembly. Furthermore, a second latch ring (), disposed between the sleeve and the inner hanger body, expands into or collapse out of the at least one inner hanger groove () and the plurality of grooves () on the sleeve (), and the second latch ring () is a tension loading support for the inner hanger body.

Tension latch tubing hanger apparatus

A testable back pressure valve for controlling fluid flow through a bore of a component installed in a well bore is disclosed. The back pressure valve includes a valve body which is configured to be secured in the bore, a flow bore which extends through the valve body, at least a first body seal which is configured to seal the valve body to the bore, and a poppet which is movably positioned in the valve body. At least a first poppet seal is sealingly engaged between the poppet and the valve body when the poppet is in the closed position, and a test port extends through the valve body to below the first poppet seal when the poppet is in the closed position. Thus, with the back pressure valve installed in the flow bore and the poppet in the closed position, the first poppet seal can be pressure tested by communicating test pressure through the test port to below the first poppet seal.

Testable back pressure valve and pressure testing system therefor

An adjustable flow line may include an outer pipe body having a first flange, an inner pipe body partially disposed within the outer pipe body and axially translatable with respect to the outer pipe body, a metal seal positioned between an outer surface of inner pipe body and an inner surface of the outer pipe body, a sleeve positioned around the inner pipe body and outside of the outer pipe body, and a second flange positioned around the inner pipe body, wherein when connected to the first flange. The sleeve may be axially translatable with respect to the inner pipe body. The second flange may axially secure the sleeve with respect to the outer pipe body and cause the sleeve to energize the metal seal.

Adjustable frac flow line

A bi-directional seal assembly for sealing the annulus between an inner tubular member and an outer tubular member comprises an annular seal which in cross section includes a generally U-shaped first portion having a radially inner first leg and a radially outer second leg and a generally U-shaped second portion having a radially inner third leg and a radially outer fourth leg. The second and third legs are joined together such that the first leg engages the inner tubular member and the fourth leg engages the outer tubular member. Pressure below the seal urges the first leg into sealing engagement with the inner tubular member and forces the second and third legs radially outwardly to thereby urge the fourth leg into sealing engagement with the outer tubular member. Also, pressure above the seal urges the fourth leg into sealing engagement with the outer tubular member and forces the second and third legs radially inwardly to thereby urge the first leg into sealing engagement with the inner tubular member.

Bi-directional seal assembly

The present invention is directed to a split locking ring for wellhead components. In one illustrative embodiment, the device comprises a first internally threaded wellhead component, a second wellhead component, at least a portion of which is positioned within an opening in the first wellhead component, and a rotatable split lock ring comprised of at least two externally threaded sections, wherein at least a portion of the sections of the split lock ring are positioned between the first and second wellhead components and rotated to threadingly couple the sections of the split lock ring to the first wellhead component and thereby secure the second wellhead component to the first wellhead component. In one illustrative embodiment, the method comprises positioning at least a portion of a first wellhead component within an opening in a second internally threaded wellhead component, positioning a split lock ring comprised of at least two externally threaded sections proximate the first and second wellhead components, and rotating the sections of the split lock ring to threadingly couple the externally threaded sections to the internally threaded second wellhead component and position at least a portion of the split lock ring sections between the first and second wellhead components, thereby securing the first wellhead component to the second wellhead component.

Growing community of inventors

Houston, TX, United States of America

Brian J Baca