Halliburton Company

Halliburton Energy Services, Inc.

Weatherford/lamb, Inc.

Baker Hughes Corporation

Frank's International, Inc.

David F Laurel

James Frank Heathman

Bobby L Sullaway

Kenneth P Marcel

Kurt Randall Koenig

Henry Eugene Rogers

David Durward Szarka

Steven George Streich

Anthony M Badalamenti

Keith T Lutgring

Earl Don Webb

Corey Eugene Hoffman

Robert B Carpenter

Burney J Latiolais, Jr

Stephen E Tilghman

John Emile Hebert

Kenneth Gregory Neal

Charles A Butterfield, Jr

Joseph Boudreaux

Samuel P Hawkins

Jason Ellis

Grant L Hartman

Jerry L Logan

Steven N Rolen

George L Morgan

Charles J Pate, Ii

Robert A Bates

Scott A Darby

Douglas K Baugher

Joseph Jude Boudreaux

Burney J Latiolais

Charles A Butterfield

Kurt R Koenig

Devices and methods are described for quickly connecting and disconnecting a conduit to a port. A quick connect coupling is described for quickly connecting and disconnecting a cement supply conduit to the port of a top drive cement swivel.

Quick connect coupling for cementing operations and the like

A subsea cementing system that includes a first wiper plug having a central bore releasably connected to a launching mandrel, and a second wiper plug having a central bore releasably connected to the first wiper plug. The system includes a first dart that is adapted to seal the central bore of the second wiper plug. A first increase in pressure releases the second wiper plug from the first wiper plug and a second increase in pressure breaks a burst disc of the first dart allowing cement to flow past the second wiper plug. A second wiper dart is adapted to seal the central bore of the first wiper plug. A third increase in pressure releases the first wiper plug from the launching mandrel. A fourth increase in pressure releases a sealing member from the second dart, which is adapted to seal the central bore of the second wiper plug.

Subsea cementing plug system with plug launching tool

Methods of using and making and apparatuses utilizing a filtered actuator port for hydraulically actuated down hole tools. The filtered port prevents sand or other debris from entering the actuator workings of a tool. In accordance with one aspect of the invention, hydraulic tools utilizing filtered actuator ports are disclosed. In a second aspect, the filtered port comprises fine slots disposed through a wall of a mandrel spaced around the circumference of the mandrel. In a third aspect, the inlet port is formed by laser cutting or electrical discharge machining. In a fourth aspect, the filtered port is disposed in various components of a fracture pack-off system. Methods of using the fracture pack-off system utilizing the filtered port are provided.

Filtered actuator port for hydraulically actuated downhole tools

The present invention generally relates to a plunger-type valve for use in a wellbore. The plunger-type valve is arranged to selectively allow fluid flow to enter and exit the valve in both directions. Subsequently, the plunger-type valve can be deactivated to selectively allow fluid flow in only one direction. The valve includes a body, at least one locking segment, a locking sleeve, at least one biasing member, a valve seat and a plunger.

Valve assembly for use in a wellbore

The present invention generally relates to a flow-actuated valve for use in a wellbore. The invention includes a body having a closing member and a seat. The closing member and seat are separable to open and close the valve, thereby allowing the flow of fluid through the valve. The invention further includes a retainer to initially retain the valve in the open position absent a predetermined fluid flow rate in a first direction for a predetermined time period. A biasing member thereafter urges the valve to the closed position, absent another fluid flow rate in the first direction.

Flow actuated valve for use in a wellbore

A downhole apparatus is described as having an upper mandrel shearably connected to a lower mandrel by a first set of shear pins. Each of the mandrels has an elastomeric cement plug formed around the mandrels. A sleeve is shearably connected within the lower mandrel. The operation of the apparatus, which includes a method for controlling the flow of fluid out of the end of a tubular string, involves dropping a first small diameter ball from the earth3 s surface. The ball is sized such that it travels through the upper mandrel and settles into the sleeve which is connected within the lower mandrel. By increasing pump pressure at the earth's surface, the lower mandrel is separated from the upper mandrel by shearing the first set of shear pins. After the separation of the lower mandrel from the upper mandrel, by further increasing the pump pressure at the earth's surface, a second set of shear pins are sheared and the lower mandrel can be pumped down to the bottom of the tubular string against a float collar or other plug landing surface. This enables the fluid within the tubular string to be pumped out of the lower mandrel into the earth borehole. When it is desired to separate the upper mandrel from the tubular string, the second, larger ball is dropped from the earth's surface and is seated within the upper mandrel. By further increasing the pump pressure, the upper mandrel is separated from the tubular string and can be pumped down against the lower mandrel.

Method and multi-purpose apparatus for control of fluid in wellbore casing

A method of indicating the release of a plug, such as a cementing plug for an oil or gas well, includes releasing a plug from a retained position in a tube system, and in response to releasing the plug, opening an electrical circuit to which the plug was connected in the retained position. The method also includes generating, in response to opening the electrical circuit, a plug release indicator signal. The indicator signal can be generated in response to, for example, a low frequency electromagnetic signal.

Plug release indication method

Improved methods and apparatus for placing and cementing a casing string in a horizontal well bore section are provided. A float shoe is attached to the end of the casing string and a float collar is connected in the casing string for trapping air in a first portion of the casing string thereby causing it to be buoyed up during placement by drilling fluid contained in the well bore. A selectively openable and releasable closed baffle assembly is connected within the casing string for trapping air or a low density fluid in a second portion of the casing string thereby causing it to also be buoyed up by drilling fluid in the well bore. The buoying up of the casing string reduces placement drag and consequent compressive loading on the casing string. After placement, the closed baffle means is opened to allow fluid circulation and conditioning of the annulus. A bottom cementing plug is then landed on the baffle assembly and the baffle assembly is released and moved to the float collar. A cement slurry is thereafter placed in the annulus and allowed to set therein.

Method and apparatus for placing and cementing casing in horizontal wells

The present invention provides an improved subsurface release cementing plug apparatus for use in a string of pipe during the cementing of the pipe in a well bore. The apparatus includes a hollow cementing plug seat member adapted to be connected in the string of pipe near the bottom thereof and a cementing plug assembly releasably connectable to a circulation tool or casing running tool in the top of the string of pipe. The cementing plug assembly includes a top cementing plug having an external annular seating surface formed thereon for sealingly engaging a top internal annular seating surface of the cementing plug seat member, and a bottom cementing plug releasably connected to the top cementing plug having an external annular seating surface formed thereon for engaging a bottom internal annular seating surface of the cementing plug seat member.

Subsurface release cementing plug apparatus and methods

A ball drop head for dropping balls into a tubing or casing string of a well. The ball drop head has a central container with at least one ball carrier ring rotatably disposed therein. A ball cavity is defined in the ring, and a ball is disposed therein. The ball is biased radially inwardly toward the container so that when the ring is rotated to align the cavity with a ball release opening defined in the container, the ball is pushed through the ball release opening to enter and fall through a central opening in the container. The ring may be rotated manually or remotely, such as by inflating a pneumatic or hydraulic bellows. Additional rings may be mounted on the container to use in dropping additional balls. A method of dropping balls into a well is also disclosed.

Ball drop head with rotating rings

An improved well cementing plug assembly adapted to be connected to a string of drill pipe or a circulation tool for use in a pipe during the cementing of the pipe in a well bore is provided. The top and bottom plugs are selectively releasable by activating balls dropped into the plug assembly. Different sizes of plugs can be used utilizing the same inner tubes and other assembly parts, and the top plug slides on its inner tube when a pressure differential is exerted on it thereby insuring a seal between the top and bottom plugs when the plugs are landed on a float shoe or the like.

Well cementing plug assemblies and methods

An inflation packer method and apparatus comprising at inflatable packer bladder and an inflation fluid. The packer apparatus further comprises a packer mandrel having a central flow passage therethrough and an outer packer body which includes the inflatable packer bladder. A chemical expanding additive is employed to expand the inflation fluid used to inflate the packer bladder. An annular inflation fluid passageway is defined between the mandrel and the body. Inflation fluid passes from the central flow passage into the annular inflation fluid passageway to inflate the inflatable packer bladder. The mandrel has grooves defined on an outer surface thereof. The chemical expanding additive is placed in grooves defined on the outer surface of the mandrel so that the expanding additive is dispersed into the fluid passing into the annular passageway.

Inflation packer method and apparatus

A method and apparatus for use in setting sidetrack plugs in a well bore. The apparatus comprises an inflation packer assembly which may be attached to the lower end of the tubing string. The packer is inflated to seal against the well bore at the lower end of the sidetrack plug. The inflation packer is attached to a tubing string with a length of tail pipe. The tail pipe is releasably attached to the tubing string. After the inflation packer is sealed against the well bore, a cementitious fluid is circulated above the bladder to form the sidetrack plug. The tailpipe is then released and the tail pipe and the inflation packer remain in the hole and form a part of the sidetrack plug. An additional embodiment includes a whipstock connected to the inflation packer assembly.

Method and apparatus for setting sidetrack plugs in open or cased well

A whipstock for use in sidetrack drilling operations in a well bore. The whipstock has a whipstock case with a whipstock body disposed therein. The whipstock is to be comprised of a drillable material so that after the whipstock has been set, the well bore can be re-opened simply by drilling through the whipstock. The whipstock body is preferably comprised of high compressive strength cement. The whipstock: also includes an offset mandrel attached to the whipstock: case. The whipstock mandrel has a whipstock bore and may have an inflation packer attached to a lower end thereof. The inflation packer is actuated through the whipstock bore to seal against the well bore and anchor the whipstock in place.

Drillable whipstock

An inflation packer apparatus includes an inflatable packer bladder and uses cementitious fluid as an inflation fluid. The packer apparatus includes a packer mandrel having a central flow passage therethrough and an outer packer body which includes the inflatable packer bladder. A chemical accelerating agent is employed to accelerate the hardening time of the cementitious fluid used to inflate the packer bladder. An annular inflation fluid passageway is defined between the mandrel and the body. Inflation fluid passes from the central flow passage into the annular inflation fluid passageway to inflate the inflatable packer bladder. The mandrel has grooves defined on an outer surface thereof. The chemical accelerating agent is placed in grooves defined on the outer surface of the mandrel so that the accelerating agent is dispersed into the fluid passing into the annular passageway.

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Duncan, OK, United States of America

David F Laurel