Weatherford/lamb, Inc.

Gerald Dean Pedersen

David Eugene Hirth

David Michael Haugen

Richard Lee Giroux

Thad Joseph Scott

Clayton Stanley Pluchek

Tarald Gudmestad

Mark J Murray

The present invention provides a downhole cementing apparatus run into a borehole on a tubular. The apparatus is constructed on the pipe in such a way that pressure surge during run-in is reduced by allowing fluid to enter the pipe and utilize the fluid pathway of the cement. In one aspect of the invention, an inner member is provided that filters fluid as it enters the fluid pathway. In another aspect of the invention, various methods are provided within the cementing apparatus to loosen and displace sediment in the borehole prior to cementing.

Downhole surge pressure reduction and filtering apparatus

Embodiments of the present invention relate to hydraulic tools which may be used to set a liner top packer and/or may be used to resist the lifting forces of cementing pack-offs. One embodiment of a tool string for use in wellbore operations comprises a hydraulic anchor assembly adapted to prevent axial movement of the tool string and a hydraulic packer actuator assembly adapted to set a packer.

Hydraulic tools for setting liner top packers and method for cementing liners

The present invention is a packer for sealing an annular region in a wellbore. The packer includes a packing element which is held through bidirectional forces. The packer first comprises an inner mandrel. Disposed around the inner mandrel are three tubulars: (1) a top sleeve; (2) a bottom sleeve; and (3) a booster sleeve. A packing element is disposed circumferentially around the outer surface of the booster sleeve. The top sleeve and bottom sleeve each include an upper compression member which rides across the booster sleeve in order to compress the packing element. The packing element is expanded outward from the packer to engage a surrounding string of casing through compressive forces provided by the top and bottom sleeves. Thereafter, differential pressure applied above or below the packer acting on the packer element and booster sleeve may provide additional compression of the packer element.

Bi-directionally boosting and internal pressure trapping packing element system

A plug-dropping container used for releasing plugs or other objects into a wellbore during fluid circulation procedures. In one aspect, the plug-dropping container is used as part of a cementing head. The plug-dropping container comprises an elongated housing, and a canister disposed co-axially within the housing. The canister is configured to receive the plug, such as a drill pipe dart. A valve is disposed below the canister. The valve is movable from a plug-retained position where the plug is blocked, to a plug-released position where the plug may be released into the wellbore there below. In the plug-retained position, fluid is permitted to flow through the canister-housing annulus and around the valve.

Plug-dropping container for releasing a plug into a wellbore

A connector arrangement used for connecting and locking tubular members. The connector consists of two tubular members and a coupling member. The tubular members are threaded together to create a threaded connection. The locking arrangement is provided by a pathway formed on the tubular member whereby a locking member can be inserted in to the pathway to lock the threaded connection. The locking arrangement is also provided by a plurality of castellation members disposed on each tubular member. The connector also has a separate coupling member which has opposite right-hand and left-hand threaded ends to threadedly mate with the threads of the two tubular members.

Locking arrangement for a threaded connector

Present invention is a packer for sealing an annular region in a wellbore. The packer includes a packing element which is held through bi-directional forces. The packer first comprises an inner mandrel. Disposed around the inner mandrel are three tubulars: (1) a top sleeve; (2) a bottom sleeve; and (3) a booster sleeve. A packing element is disposed circumferentially around the outer surface of the booster sleeve. The top sleeve and bottom sleeve each include an upper compression member which rides across the booster sleeve in order to compress the packing element. The packing element is expanded outward from the packer to engage a surrounding string of casing through compressive forces provided by the top and bottom sleeves. Thereafter, differential pressure applied above or below the packer acting on the packer element and booster sleeve may provide additional compression of the packer element.

A method and apparatus for obstructing the passage of fluid within a fluid flow conduit and subsequently reconfiguring the tool to allow substantially full-bore passage therethrough. Pressure developed upstream of the obstruction can be utilized to operate pressure actuated tools such as liner hangers. Equipment used in subsequent wellbore operations such as drill pipe darts can pass undamaged through the opened port. In an embodiment, the flow through a tubular is obstructed by placing a ball on an expandable ball seat, developing a pressure differential across the ball seat, equalizing the pressure after the hydraulically actuated tool completes its function, and mechanically manipulating the drill string to open the expandable ball seat and allow the ball to pass through.

Mechanically opened ball seat and expandable ball seat

A ball dropping assembly for dropping a plurality of objects, such as spherical balls, into a wellbore. The assembly first comprises a seat for retaining a ball before it is released. The assembly also comprises a ball-feeding channel for feeding additional balls onto the seat. A ball-retaining lever is provided to selectively receive and retain balls onto the seat, and then to release the balls individually into the wellbore. In one embodiment, the assembly is attached to a side bore in fluid communication with a main bore in a cementing head. The ball-retaining lever rotates into the bore when releasing a ball. When a plug is released into the bore from a cementing head, the plug will trip the lever, causing the ball-retaining lever to rotate back towards the ball-retained position. Thus, the ball dropping assembly also serves as a plug release indicator.

Ball dropping assembly

A ball dropping assembly for dropping an object such as a spherical ball into a wellbore. The assembly comprises a seat for retaining a ball before it is released, a ball retaining lever, and a shaft for turning the lever. In one embodiment, the assembly is attached to a side bore in fluid communication with a main bore in a cementing head. The ball-retaining lever has at least one finger which is rotated between a ball-retained position and a ball-released position. In the ball-retained position, the first finger is disposed in the entrance from the side bore to the main bore, thereby preventing the ball from entering the main bore of the cementing head. When the ball is ready for release, the lever is rotated in the direction of the main bore, thereby causing the second finger to urge the ball into the bore of the cementing head, and causing the first finger to protrude into the main bore. When a plug is released into the bore from the cementing head, the plug will trip the first finger, causing the ball-retaining lever to rotate back towards the ball-retained position. Thus, the ball dropping assembly also serves as a plug release indicator.

The present invention relates to a plug-dropping container for releasing plugs or other objects into a wellbore during fluid circulation procedures. In one aspect, the plug-dropping container is used as part of a cementing head. The plug-dropping container comprises an elongated housing, and a canister disposed co-axially within the housing. The canister is movable from a lower position to an upper position. In its lower position, a fluid bypass area is defined above the canister. When a dart is retained within the canister, fluid is diverted through the bypass and around the canister within an annular area defined between the canister and the housing. In one aspect, the canister is moved by rotation of a plug-retaining device below the canister. In its plug-retained position, the plug-retaining device is oriented so that the wall of the plug-retaining device is blocking the downward path of the dart. In the plug-released position, the plug-retaining device raises the canister to its upper position, substantially shutting off the bypass. A channel in the plug-retaining device is thus aligned with a channel in the canister for receiving the plug, and for release into the wellbore.

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Houston, TX, United States of America

Gerald Dean Pedersen