Impact Selector International, LLC

Isodrill, Inc.

Weatherford Technology Holdings, LLC

James Patrick Massey

Brandon Martin

Jason Allen Hradecky

Stephen D Bonner

Raymond V Nold, Iii

Saad Bargach

Jon Brunetti

Jeremy Todd Morrison

Thomas Wilson

Edward Saville

Travis Hubbard

Jon A Brunetti

Raymond V Nold Iii

Raymond V Iii Nold

An impact jar apparatus including a dynamic portion connectable to an upper tool string portion, a static portion connectable to a lower tool string portion, and a hydraulic manifold, an activation indicator, a relatch assist, and/or a shock absorber. The hydraulic manifold fluidly communicates with an annulus between the dynamic and static portions. The hydraulic manifold adjusts a delay between application of a trigger tension and consequent activation of the impact jar apparatus. The activation indicator, including a wire coil in the static portion and magnets carried by the dynamic portion, generates a magnetic field whereby a voltage pulse is generated in the wire coil in response to the magnetic field passing the wire coil upon activation of the impact jar apparatus. The relatch assist urges the dynamic and static portions toward a latched position. The shock absorber absorbs axial shock generated by activation of the impact jar apparatus.

Impact jar delay, activation indicator, shock absorber, and relatch assist

An explosive assembly for a downhole tool operable to connect and selectively disconnect within a wellbore a first portion of a downhole tool string and a second portion of the downhole tool string. The explosive assembly includes an explosive charge, a detonator switch operable to detonate the explosive charge, and a housing assembly containing the explosive charge and the detonator switch. The explosive assembly may be movable as a single unit and installable within an internal space of the downhole tool. The explosive charge may be operable to sever a support member of the downhole tool when the explosive charge is detonated by the detonator switch to therefore disconnect a first portion of the downhole tool and a second portion of the downhole tool from each other and thus disconnect the first portion of the downhole tool string and the second portion of the downhole tool string from each other.

Downhole apparatus

A downhole conveyance line cutter operable to be conveyed downhole within a wellbore along a conveyance line that conveys a tool string within the wellbore, connect to the conveyance line, and cut the conveyance line. The downhole conveyance line cutter may comprise a body, a cutting member operable to cut the conveyance line, and a nose section configured to contact an upper end of the tool string when the downhole tool reaches the tool string. The nose section may comprise an outer diameter that is larger than an outer diameter of the body. The nose section may comprise a contact surface configured to contact the upper end of the tool string when the downhole tool reaches the tool string. The contact surface may be a concave surface configured to accommodate at least a portion of the upper end of the tool string.

Downhole conveyance line cutter

A downhole conveyance line cutter operable to be conveyed downhole within a wellbore along a conveyance line that conveys a tool string within the wellbore, connect to the conveyance line, and cut the conveyance line. The downhole conveyance line cutter may comprise a body, a cutting member operable to cut the conveyance line, and a clamping mechanism operable to connect the downhole conveyance line cutter to the conveyance line. The clamping mechanism may comprise a clamping member pivotably connected with the body and an actuator operable to pivot the clamping member to cause the clamping member to engage the conveyance line thereby connecting the downhole tool to the conveyance line such that the downhole tool can be retrieved out of the wellbore via the conveyance line after the downhole tool cuts the conveyance line.

A downhole tool operable to connect within a downhole tool string. The downhole tool may include a first sub, a second sub, and a movable joint movably connecting the first sub and the second sub to facilitate relative angular movement between the first sub and the second sub. The downhole tool may be operable to connect together a first portion of the tool string and a second portion of the tool string and facilitate relative angular movement between the first portion of the tool string and the second portion of the tool string when the downhole tool is connected within the tool string.

Downhole movable joint tool

A wheel assembly configured to detachably connect to a downhole tool to thereby reduce friction between the downhole tool and a sidewall of a wellbore through which the downhole tool is conveyed. The wheel assembly may include an axle configured to contact a sidewall of the downhole tool, wherein the axle comprises a bore extending therethrough, a wheel rotatably connected to the axle such that the wheel extends around at least a portion of the axle and the bore, and a fastener configured to be disposed at least partially within the bore and extend out of the bore into the sidewall of the downhole tool to detachably connect the axle to the downhole tool.

Wheel assembly

A downhole conveyance line cutter operable to be conveyed downhole within a wellbore along a conveyance line that conveys a tool string within the wellbore and then cut the conveyance line. The downhole conveyance line cutter may have a body, a fluid chamber within the body, a piston slidably disposed within the fluid chamber, a knife that is movable with respect to the body, an arm operatively connecting the piston and the knife, and a fluid source operable to pump a fluid into the fluid chamber to cause the piston to move the arm which moves the knife to cut the conveyance line.

A wheel assembly and a method for detachably connecting the wheel assembly to a downhole tool to reduce friction between the downhole tool and a sidewall of a wellbore through which the downhole tool is conveyed. The wheel assembly may include an axle configured to contact a sidewall of the downhole tool, a wheel rotatably connected with the axle, and a fastener configured to extend into the sidewall of the downhole tool to detachably connect the axle to the downhole tool.

An apparatus and method for performing automated pump-down operations. An apparatus may include a control system configured to be communicatively connected with a fluid pump disposed at a wellsite surface and with a conveyance device disposed at the wellsite surface. The control system may be operable to cause the conveyance device to unwind a conveyance line connected with a tool string disposed within a wellbore, and cause the fluid pump to pump a fluid into the wellbore such that the fluid moves the tool string along the wellbore while the conveyance device unwinds the conveyance line.

Automated pump-down

A downhole tool for connecting with a conveyance line. The downhole tool may include a body configured to receive the line and a fluid seal operable to seal against the line when the downhole tool is connected with the line to inhibit wellbore fluid from entering the body when the downhole tool is conveyed within a wellbore via the line. The downhole tool may include a fluid seal slidably disposed within the body and operable to seal against an inner surface of the body to inhibit wellbore fluid from entering the body when the downhole tool is conveyed within the wellbore. The body may include a first body and a second body connected together, wherein the first body is operable to move with respect to the second body when a predetermined tension is applied to the line from the wellsite surface to cause the downhole tool to release the line.

Downhole tool for connecting with a conveyance line

A downhole tool for connecting with a conveyance line. The downhole tool includes a first body and a second body. The first body and second body are connected together, wherein the first body is operable to move with respect to the second body when a predetermined tension is applied to the line from a wellsite surface to cause the downhole tool to release the line. The first body and second body may be connected together via a plurality of pins, wherein the pins are configured to break when the predetermined tension is applied to the line from the wellsite surface to cause the downhole tool to release the line. The downhole tool may comprises a line end termination device operable to connect with the line. The line end termination device is operable to release the line when the predetermined tension is applied to the line from the wellsite surface.

A downhole release apparatus having a first connector sub connectable with a first portion of a tool string and a second connector sub connectable with a second portion of the tool string. The first connector sub may include a housing, a first latching member, and a blocking member. The second connector sub may include a second latching member. The first and second latching members may engage thereby connecting the first and second connector subs. The blocking member may be movable from a first position in which the blocking member prevents the first and second latching members from disengaging to a second position in which the blocking member permits the first and second latching members to disengage thereby permitting the first and second connector subs to disconnect. Relative movement between the housing and first latching member may facilitate movement of the blocking member from the first position to the second position.

Downhole release apparatus

A downhole impact apparatus operable to impart an impact to an object within a wellbore. The impact apparatus may include a housing, a first chamber within the housing, a second chamber within the housing, and a piston assembly slidably disposed within the housing. The piston assembly may include a first piston slidably disposed within the first chamber and dividing the first chamber into a first volume and a second volume, a second piston slidably disposed within the second chamber, and a shaft connecting the first and second pistons. The first volume may be open to a space external to the housing and the second volume may be fluidly isolated from the space external to the housing. Relative movement between the piston assembly and the housing ends with the impact. The second chamber may be configured to contain a fluid to prevent relative movement between the piston assembly and the housing.

Downhole impact apparatus

Apparatus and methods for running casing into a wellbore. An apparatus may be or include a casing collar configured to couple together a first casing joint and a second casing joint. The casing collar may have a body and a plurality of rotatable members connected to the body. The body may have a fluid passage extending axially therethrough, a first coupler configured to couple the casing collar with the first casing joint, and a second coupler configured to couple the casing collar with the second casing joint. At least a portion of each rotatable member may extend from the body in a radially outward direction.

Apparatus and method for running casing into a wellbore

A downhole centralizer operable to be coupled with a tool string and conveyed within a downhole passage, wherein the downhole passage is a wellbore or a tubular member disposed in the wellbore. The downhole centralizer may have a plurality of arms that are operable to move against a sidewall of the downhole passage to centralize at least a portion of the tool string within the downhole passage, impart an intended force against the sidewall of the downhole passage, and maintain the intended force substantially constant while the tool string is conveyed along the downhole passage and an inner diameter of the downhole passage changes.

Growing community of inventors

Breckenridge, CO, United States of America

James Patrick Massey