Weatherford Technology Holdings, LLC

Weatherford/lamb, Inc.

Patriot Research Center, LLC

Fmc Technologies, Inc.

Brandon Matthew Cain

Todd Travis

Eric Calzoncinth

Craig L Cotton

Paul Perez

Gerald Brian Swagerty

Huy LeQuang

Bill Albright

Jean-Luc Jacob

Richard C Jones

Michael L Bilyeu

Gordon Ronnie Altman

Steve Willard

Michael D Mosher

Carl Edwin Davidson

John A Rogers

Ping Cai

Manish Agarwal

Joseph Opitz

Robert Scott Menard

Mike D Mosher

Clark E Robison

Jeffrey John Lembcke

Paul L Smith

Sean Michael Christian

Benson Thomas

Bryan A Paulet

William C Lane

Darius John Yakimchuk

Elizabeth McClain

Michael Pursley

Scott Menard

Genith Del Carmen Guitierrez

Jason A McGinnis

Michael Mosher

Jason A Mcginnis

Genith Guitierrez

Elizabeth A Mcclain

Huy Lequang

A hydraulic accumulator system is provided to remove the motors or engines from the red zone while maintaining sufficient capacity within the red zone to quickly close the designated blowout preventer or other gate valves. Additionally, a single point is provided outside of the red zone to charge the local storage units or to open or close the designated blowout preventer or other gate valves when time is not a critical consideration.

Hydraulic accumulator system

A greasing system may be placed partially within the red zone and partially outside of the red zone. Grease and pneumatic power is supplied from outside of the red zone to a pod, inside of the red zone, having local storage, high-pressure pumping capacity, and a distribution mechanism. The grease is supplied from outside of the red zone to the pod at low-pressure through a hose having at least a 1 inch inside diameter and is usually at least 100 feet long. The pod pressurizes the grease to a high-pressure and distributes the grease via a distribution mechanism to a relatively short hose, generally less than 8 feet between the distribution mechanism and the greasing point on the wellhead, in order to minimize pressure losses.

Frack valve greasing system

A rotary multiport greasing valve having an outer sleeve and an inner sleeve within the outer sleeve. The outer sleeve has at least one inlet port and at least 2 outlet ports. The inner sleeve has an inlet port, a central passageway, and an outlet port. The inner sleeves inlet port is fluidly connected to the outer sleeve's inlet port. The inner sleeve rotates within the outer sleeve so that the inner sleeves outlet port is circumferentially aligned with a selected outer sleeve outlet port creating a fluid pathway from the outer sleeve inlet port into the inner sleeve's inlet port through the central passageway through the inner sleeve's outlet port and finally through the outer sleeves outlet port to create an open flowpath. In certain instances, the inner sleeve inlet port is longitudinally shifted so as not to align with any portion of an outlet sleeve outlet port.

Rotary multi-port greasing valve

An isolation tool is provided that includes an upper elastomer, a lower elastomer. The isolation tool when set provides a circumferential flow path between the elastomers. The isolation tool also includes a longitudinal flow path from above the isolation tool to below the isolation tool. The longitudinal flowpath is preferably sufficiently linear that a solid tool may be passed through the longitudinal flowpath from above the isolation tool to below the isolation tool.

Isolation tool

A system to provide at least two circumferential metal to metal seals between coaxial tubulars. Where a first tubular includes a circumferential shoulder having a circumferential first metal seal and a circumferential second metal seal. A second tubular has a circumferential shoulder that matches and abuts the first tubular circumferential shoulder. Each metal seal is of a material having a higher yield strength than the second tubular shoulder such that the first metal seal and the second metal seal will penetrate the material of the second tubular shoulder thereby providing a seal. Additionally a test port is provided from the exterior of the exterior tubular to a point on either the first or second tubular between the first and second metal seals.

Metal to metal vee seal

An inwardly biased tubing hanger is provided that allows for continued turns in the same direction to both lock the tubing hanger in place within the well as well as release the running tool from the tubing hanger. An energizing sleeve and running tool each having left hand threads is provided where a torque ring between the energizing sleeve and running tool allows the running tool to be turn in the right hand direction until sufficient torque is provided to the torque sleeve to release the running tool from the energizing sleeve. With the running tool attached to the energizing sleeve the energizing sleeve provides sufficient force, provided the torque limit of the torque sleeve is not been reached, to drive the inwardly biased torque ring radially outward.

Inward biased tubing hanger

A modular assembly for a wellhead has a housing and a plurality of modular cartridges. The housing connects with a studded or flanged connection to the wellhead, which can have a tubing adapter, casing hanger, etc. The modular cartridges can interchangeably stack in the housing's internal pocket so that the bores of the stacked cartridges configure the through-bore of the assembly communicating the wellhead with external components, such as flow lines, capillary lines, etc. The modular cartridges include a spacer cartridge, a hanger cartridge, a valve cartridge, and a cross cartridge. The spacer cartridge can be used to space other cartridges in the internal pocket, and the hanger cartridge can be used to support capillary strings and/or velocity strings in the wellhead. The valve cartridges have valve elements that can be opened and closed by bonnets that affix externally to the housing. The cross cartridge can have one or more cross ports to divert the assembly's through-bore to additional flow components, such as flow lines, wing valves, chokes, and the like.

Cartridge valve assembly for wellhead

A long-stroke pumping unit includes a tower; a counterweight assembly movable along the tower; a drum connected to an upper end of the tower and rotatable relative thereto. The unit also includes a belt having a first end connected to the counterweight assembly, extending over the drum, and having a second end connectable to a rod string. The unit further includes a prime mover for reciprocating the counterweight assembly along the tower; a sensor for detecting sudden acceleration of the counterweight assembly due to failure of the rod string; and a controller in communication with the sensor and operable to activate the braking or arrestor system in response to detection of the sudden acceleration. The unit further includes at least one of a braking system for halting free-fall of the counterweight assembly; and an arrestor system for absorbing kinetic energy of the falling counterweight assembly.

Long-stroke pumping unit

On a wellhead, a well component, such as a casing head, has a bowl with a first shoulder and a groove defined therein. A hanger for supporting casing positions in the bowl, and a latch assembly on the hanger latches the hanger in the groove. The latch can have a traveling ring and a latch ring supported on the hanger's exterior surface. The traveling ring engages the first shoulder in the bowl and pushes the latch ring against a portion of the hanger, such as a second shoulder. The latch ring has a joint at a split in the latch ring, and the joint holds the latch ring in a compressed state about the exterior surface. When the latch ring moves with the engagement of the traveling ring against the hanger portion, the joint is disjointed, and the latch ring expands outward into the groove to latch the hanger in the bowl.

Composite fracture plug and associated methods

To deploy a capillary string through a wellhead to a downhole safety valve, a control port and a retention port are drilled in an adapter between a casing hanger and a gate valve or elsewhere. The capillary string is connected to a first port of a capillary hanger and installed through the wellhead. The capillary hanger is landed on a tubing hanger, and a side port on the capillary hanger communicates with the control port. Because the side port's location may not align with the control port, operators may need to measure how long the capillary hanger should be. A control line connects to the control port in the wellhead's side to communicate with the capillary line, and a retention rod inserts in the retention port to support the capillary hanger.

Method for deploying subsurface safety valve having integral pack off

A wellhead completion assembly has a head connected to surface casing. A rotatable flange or the like can be used to connect various components to a threaded end of the head. A casing hanger installs in the head, and the hanger's upper end extends beyond the head's top edge. This exposed end has an external threaded connection to connect to various wellhead components using a rotatable flange or the like. For example, a locking ring can threadably connect to the head's threaded end to support the hanger in the head. Then, a rotatable flange can threadably connect to the hanger's exposed end so that another component, such as a completion spool or gate valve, can nippled up directly to the hanger. When the hanger is fluted, a pack-off assembly can allow testing off inner and outer sealing integrity via a test port accessible through an opening in the locking ring.

Wellhead completion assembly capable of versatile arrangements

A slip on nut and reverse cut die is provided for dressing the threads of a wellhead or other item. A nut is provided that may be slipped onto a threaded section, past any damaged threads, without engaging the threads of the threaded section. Once positioned on a threaded section the nut may be tightened as desired. When removing the nut the reverse edges of the nut may repair or even cut new threads into the threaded section.

Adjustable die

Hydraulic flange connectors connect two flange components together, and hydraulic pressure applied to ports in connector holes of one of the flanges tension the flange studs and crush the gasket between the flange components. Each connector has a piston that disposes in the connector hole and can move therein when hydraulic pressure is applied through the port by a pump. A first stud connected to the piston extends beyond one open end of the hole for connection to a first nut, while a second stud connected to the piston extending beyond another open end of the to the second flange component for connection to a second nut. A retainer having seals threads in this other open end of the hole and seals between the hole and the second stud.

Hydraulic tensioning flange connector method

Growing community of inventors

Houston, TX, United States of America

Brandon Matthew Cain