Halliburton Energy Services, Inc.

Kendall Lee Pacey

Matthew Todd Howell

Jesse Cale Porter

William Ellis Standridge

Jimmie Robert Williamson

Donald R Smith

Matthew James Merron

Perry C Shy

Kevin T Berscheidt

Roger Charles Watson

Daniel Lee Schmidt

Brian Keith Ogle

Matt Brian Roseman

Kevin Thomas Berscheidt

William Ellis Stanridge

Disclosed herein is a seat assembly for a drill string, the seat assembly having an outer tubular member and a seat disposed therein. The seat has a bore having a central axis. A plurality of cuts extends radially from the bore to an outer perimeter of the seat, the plurality of cuts also extending a distance longitudinally along the length of the central axis. Each of the plurality of cuts is present at an angle oblique to the peripheral circumference of the bore.

Adjustable seat assembly

Disclosed herein is a segmented seat for use in wellbore servicing systems, comprising an annular-shaped seat with an upward facing surface for receiving an obturator, the seat defining a central passageway. The segments are locked together at their faces by protrusions and matching recesses.

Interlocking segmented seat for downhole wellbore tools

A segmented seat adapted to be placed in subterranean wellbore equipment and engaged by an obturator. The segmented seat includes an annular body that is radially divided into a plurality of separate segments, the annular body defining a central bore extending axially therethrough, a generally cylindrical outer wall, and an end wall; an annular seat formed on the end wall and extending about the central bore of the annular body, the annular seat being of a size and shape to engage the obturator; at least one recess formed into each of the segments and offset from the outer wall of the annular body so that at least a portion of the annular body is located radially between the outer wall and the recess; and a non-metallic material disposed within the recess and joining adjacent segments together.

Segmented seat for wellbore servicing system

A wellbore servicing system, comprising a sleeve system comprising a ported case, a sliding sleeve within the case and movable between a first sleeve position in which the sleeve restricts fluid communication via the case and a second sleeve position in which the sleeve does not, a radially divided segmented seat movable between a first seat position in which the seat restricts movement of the sleeve and a second seat position in which the seat does not, and a sheath covering a portion of the seat, the sleeve system being transitionable from a first, to a second, to a third mode, in the first mode, the sleeve is in its first position and the seat in its first position, in the second mode, the sleeve is in its first position and the seat in its second position, and, in the third mode, the sleeve is in its second position.

System and method for servicing a wellbore

A wellbore servicing system comprising a pressure testing valve incorporated within a casing string and comprising a housing comprising one or more ports and an axial flowbore, a sliding sleeve, wherein the sliding sleeve is positioned within the housing and transitional from a first position to a second position through a sliding sleeve stroke, wherein, in the first position, the sliding sleeve blocks a route of fluid communication via the one or more ports and, in the second position the sliding sleeve does not block the route of fluid communication via the one or more ports, wherein the pressure testing valve is configured such that application of a predetermined pressure to the axial flowbore for a predetermined duration causes the sliding sleeve to transition from the first position to the second position, wherein the predetermined duration is at least about one minute.

Interruptible pressure testing valve

A wellbore servicing system and method are disclosed. The wellbore servicing system includes a casing string, a pressure testing valve, and a floating piston assembly. The pressure testing valve includes a housing and a sliding sleeve. The floating piston assembly is slidably disposed between the housing and the sliding sleeve. The sliding sleeve is slidably positioned within the housing and is transitional from a first position to a second position and from the second position to a third position. When the sliding sleeve is in the first or second positions, it blocks fluid communication via ports in the housing.

Pressure testing valve and method of using the same

A downhole tool and system for actuation of the tool. The tool includes a sliding sleeve assembly that is urged toward an opening position due to an interior pressure in the tool. A shear pin assembly hold the tool in the closed position. As pressure is increased to above a predetermined locking set point, a locking mechanism on the sliding sleeve radial engages the housing of the tool to lock the sliding sleeve to the housing. As pressure is further increased to a predetermined an activation set point, the shear pin assembly shears, but the sliding sleeve is maintained in the closed position by the locking mechanism. Only after the interior pressure is subsequently lowered to below a predetermined opening set point will the sliding sleeve shift to an open position.

Tool with pressure-activated sliding sleeve

A wellbore system suitable for conducting pressure testing of wellbore equipment. The system comprises a casing and a pressure testing valve incorporated within the casing. The pressure testing valve further comprises a sleeve positioned within a housing and transitional from a first to a second position, and from the second to a third position. When the sleeve is in the first and second positions, the sleeve blocks a route of fluid communication via one or more housing ports. When the sleeve is in the third position the sleeve does not block fluid communication. The pressure testing valve is configured such that the sleeve transitions from the first position to the second position when a force in the direction of the second position is applied to the sleeve. When in the second position, a reduction of the force in the direction of the second position to the sleeve causes the sleeve to transition to the third position.

A wellbore servicing system and method are disclosed. The wellbore servicing system includes a casing string and a pressure testing valve. The pressure testing valve includes a housing, a sliding sleeve, and a deactivatable locking assembly. The housing includes ports and an axial flowbore. The sliding sleeve is positioned within the housing and is transitional between first, second, and third positions. When the sliding sleeve is in the first and second positions, the sliding sleeve blocks fluid communication via the ports. When the sliding sleeve is in the third position, it does not block such fluid communication. Application of a fluid pressure transitions the sliding sleeve from the first to the second position, and a reduction in fluid pressure transitions the sliding sleeve from the second to the third position. When activated, the locking assembly inhibits movement of the sliding sleeve toward the third position.

Disclosed herein is a segmented seat for use in wellbore servicing systems, comprising an annular-shaped seat with an upward facing surface for receiving an obturator, the seat defining a central passageway. The seat comprises one or more slots or passageways and, wherein at least one slot or passageway extends continuously between seat segments. The at least one slot or passageway contains a nonmetallic material suitable for retaining the segments together yet frangible or flexible enough to allow the segments to separate when forced to do so. The segments have gripping surfaces which prevent or inhibit rotation of the seat during removal.

Disclosed herein is a wellbore servicing system, comprising a tubular string, a first sleeve system incorporated within the tubular string, the first sleeve system comprising a first sliding sleeve at least partially carried within a first ported case, the first sleeve system being selectively restricted from movement relative to the first ported case by a first restrictor while the first restrictor is enabled, and a first delay system configured to selectively restrict movement of the first sliding sleeve relative to the first ported case while the first restrictor is disabled; a second sleeve system incorporated within the tubular string, the second sleeve system comprising a second sliding sleeve at least partially carried within a second ported case, the second sleeve system being selectively restricted from movement relative to the second ported case by a second restrictor while the second restrictor is enabled.

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Duncan, OK, United States of America

Kendall Lee Pacey