Petroquip Energy Services, Llp

Weatherford/lamb, Inc.

Colt Petroleum Technology, LLC

Charles David Wintill

William John Darnell

Rodney Wayne Long

William Ryle Darnell

Michael Chad Darby

Todd Ulrich Chretien

Robert Joe Coon

Robert Coon

Khai Tran

Henry Joe Jordan, Jr

Tracy Dean Blanton

Antonio Bermea Flores

Todd Ulrich Chretien, Sr

Barbara Jan Bailey

In an embodiment is provided a valve that includes a housing, a mandrel connected to the housing and defining an interior volume therebetween, a sleeve having a first end and a second end, the sleeve movably disposed in the interior volume, a chamber defined in the interior volume, the chamber having a first end and a second end, an inlet of a metering device coupled to the second end of the chamber, and an outlet of the metering device adjacent to the first end of the sleeve. In another embodiment is provided a method of using a valve that includes introducing pressure to a central bore of the valve such that a sleeve of the valve moves from a closed, locked position to a test position. The closed, locked position and the test position do not permit fluid communication between a central bore and an exterior of the valve.

Downhole valve and method of use

A clamping apparatus allowing a downhole line to be fed between downhole tubular members. The clamping apparatus can include a first and second half, each including: support arms with inner surfaces, connecting walls, and grips. The first and second halves can be selectively connectable. The clamping apparatus can include handles, hinges, and latches. A system for feeding a downhole line between an outer tubular member and an inner tubular member can include an outer tubular member disposed about an inner tubular member, wherein the clamping apparatus is disposed about the inner tubular member.

Control line feed through clamp

A downhole shifting mechanism having an inner tubular member, an outer tubular member, a piston, a first set of teeth, a sliding block, a body lock ring, a first flow path, and a second flow path is described herein. A downhole assembly can include the downhole shifting mechanism with a downhole tool connected to a second end of the downhole shifting mechanism. Also described is a method for shifting a downhole tool disposed within a wellbore.

Downhole tool shifting mechanism and method for shifting a downhole tool

A method for feeding a downhole line between two tubulars is provided. The method can include connecting a clamping apparatus about a first tubular member. The method can include supporting a second tubular member with a support surface of the clamping apparatus, feeding a downhole line through a pass through channel formed between the clamping apparatus and a tubular member, and communicating the downhole line with a tool. The clamping apparatus can include two halves, each with support arms, connecting walls, and grips.

Method for feeding control lines for drilling or workovers

One or more embodiments of a selectively openable and closable downhole tool. The wherein, the downhole tool can include an outer tubular member having an annulus port formed therethrough. The downhole tool can also include an inner tubular member. The inner tubular member can include an inner port. The inner port and annulus port can be selectively aligned to form a flow path therethrough by moving the inner tubular member relative to the outer tubular member. The downhole tool can also include a logic drum configured to selectively move the inner tubular member. The downhole tool can also include a piston assembly configured to move the logic drum.

System for controlling hydrocarbon bearing zones using a selectively openable and closable downhole tool

A formation saver sub or pump out sub incorporating an anti-surge feature. The sub includes a body, a mandrel, a piston (or an annulus fluid pressure chamber and a tubular pressure chamber), a sleeve, a spring, a releasable seat, and a plug. The plug and seat are released from the sub when one or more dogs releasably positioning the seat in the mandrel bore disengages from the seat due to a bleed off of fluid pressure in the well bore.

Formation saver sub and method

A multiple-positioning mechanical shifting system including for used in hydrocarbon wells. The system includes a shifting tool capable of selectively positioning a mechanical sliding sleeve valve in multiple operational positions that varying the flow rate and/or volume of tubing string fluid flowing to the well annulus. The system also includes a multiple position mechanical choke valve. A method of operating the mechanical choke valve using the shifting tool is described.

Multiple-positioning mechanical shifting system and method

A bypass device for bypassing a hydraulic piston in a wellbore with an outer tubular body. The outer tubular body can have a fluid control manifold. The fluid control manifold can have two control paths, two high pressure fluid paths, and two valves connecting with two high pressure fluid connecting paths. An inner tubular body can be disposed within the outer tubular body, and a piston chamber can be disposed between the inner tubular body and the outer tubular body. The piston chamber can include two piston chamber sections separated by a hydraulic piston.

Bypass device for wellbores

A downhole filter with a filter housing having a top filter and a bottom filter disposed therein. The filter housing can be in fluid communication with each filter. Each filter can be in fluid communication with a burst disk housing having a burst disk module and a burst disk. Each burst disk housing can be in fluid communication with the filter housing. Fluid can flow through the filter housing and through the filter. When a filter is clogged, the fluid can burst a burst disk, thereby bypassing the filter. The downhole filter can include a middle sub in fluid communication with the top filter and a second portion of the filter housing. The middle sub can threadably engage a bottom burst disk housing.

Filter sub

A method for connecting control lines to well bore equipment for controlling a well on a batch basis. A batch basis as used herein can mean that the well is controlled periodically. A first half of the pin connector can be formed by securing an extending hydraulic wet connector to a lower tubular portion. The lower tubular portion can have a lower tubular body, a first pin, and a lower hydraulic flow path.

Method of connecting control lines to well bore equipment for controlling a well on a batch basis

A double pin connector with hydraulic connect and seal assembly having a top portion. The top portion has an upper tubular portion. The upper tubular portion engages an intermediate tubular portion. The intermediate tubular portion has an upper flow path in fluid communication with the first hydraulic connector and a plurality of seals comprising at least one second hydraulic flow path seal.

Double pin connector and hydraulic connect with seal assembly

A method for injecting fluid into a well or producing fluid from a well comprising providing one or more single fluid line sliding sleeve downhole tool assemblies into a well in a closed position, applying a first pressure from a fluid source simultaneously to open at least one of the single fluid line sliding sleeve downhole tool assemblies, and allowing fluid to move into tubing or into a reservoir. The method contemplates the use of multiple single fluid line sliding sleeve downhole tool assemblies, wherein the first pressure causes only one of the tool assemblies, or one operably connected plurality of tool assemblies, to be in an open position at any time.

Method for flowing fluid into or from a well

A completion system for a well including an upper production tubing disposed within a wellbore. An upper packer engaging the upper production tubing a top pin connector with seal assembly engaging the upper packer. A first intermediate production tubing disposed between the top pin connector with seal assembly and a top hydraulically operated tool.

Completion system for a well

A system for controlling zones of fluid flow in and out of a wellbore. The wellbore has a top of a well and a bottom of a well. The system has a control line connected to a power source, and a control system; wherein the control line is disposed within the wellbore. The system also has a single fluid line sliding sleeve downhole tool assembly connected to the control line disposed within the wellbore.

Growing community of inventors

Houston, TX, United States of America

Charles David Wintill