Baker Hughes Corporation

Halliburton Energy Services, Inc.

Graham E Farquhar

Mark Kendall Adam

Robert C Smith

Matthew J Tabinor

Max Ogilvie

David A Hardie

John Strachan Nicoll

Steven J Drummond

A packing element and a sealing element is disclosed. The packing element includes a sealing element positioned on an outer surface of a mandrel deployed in the wellbore, where the sealing element is disposed in an annulus between the mandrel and a portion of the wellbore. The sealing element includes a first cavity on an inner surface of the sealing element, where the first cavity has a first size and is positioned proximate a first end of the sealing element. The sealing element also includes a second cavity on the inner surface of the sealing element, where the second cavity has a second size that is different from the first size, and is positioned proximate a second end of the sealing element. The packing element also includes a first and second gauge rings positioned at first and second ends of the sealing element, respectively.

Packing element with timed setting sequence

A well tool for sealing against a wall of well includes an elongate mandrel. A seal assembly encircles the mandrel and can change between an unset state and an axially compressed set state. The seal assembly includes an annular elastomer seal element configured to radially deform into contact with the wall of the well in the set state. An annular anti-extrusion ring is included to compress the seal element and form a containing space with a garter spring embedded in the seal element. The garter spring is embedded in the seal element adjacent the axial end of the seal element and configured to span the gap between the anti-extrusion ring and the wall of the well in the set state. The containing space can prevent the seal element from excessive deformation.

Sealing annular gaps in a well

An antiextrusion backup system includes an inner expandable backup ring having a first set of slots. An outer expandable backup ring having a second set of slots wherein the outer expandable back up ring is rotationally locked to the inner expandable backup ring to prevent an extrusion gap in an expanded condition of the backup rings. A method for operating within a tubular is also included.

Anti-extrusion backup system, packing element system having backup system, and method

A recess shoe system includes a recess shoe an insert sleeve disposed radially inwardly adjacent of the recess shoe in a portion of the recess shoe. The insert sleeve includes a ring and a plurality of fingers extending from the ring, the fingers being radially outwardly deflectable in response to a radially outwardly directed force. The force is generated by a swage in a swaging position acting on an inside dimension of the insert sleeve, and the insert sleeve is radially inwardly retractable when the radially outwardly directed force is removed such that the fingers of the insert sleeve define a tubular structure having an outside dimension smaller than an outside dimension of the swage in the swaging position and method.

Insert sleeve forming device for a recess shoe

A first, expandable casing member, in an unexpanded state, is provided with a lower axial end that has a radially expanded upset or recess shoe and a locating profile. The first casing member is run into a wellbore, expanded, and secured in place within the wellbore. A second expandable casing member is then provided in an unexpanded state and disposed into the wellbore through the first casing member using a running tool. The second casing member is located with respect to the first casing member and expanded using an expansion member carried by the running tool.

Grooved expandable recess shoe and pipe for deployment of mechanical positioning devices

An improved lubricator valve arrangement for use within a wellbore to allow the passage of tools, such as perforating guns and the like, into the wellbore while it is live. The inclusion of two, independently controllable flapper-type safety valves within the lubricator valve will permit coordinated testing of fluid pressure both above and below the lubricator valve. The upper flapper valve includes a rotational flip-flap arm arrangement to positively open and close the upper flapper valve. The lower flapper valve is equipped with an integrated poppet-style pressure equalizing valve to allow the lower flapper valve to be opened more easily. The direction of opening of the flapper valves precludes or reduces the risk debris-related problems that might prevent or hinder opening of the flapper valves.

Lubricator valve with rotational flip-flap arm

A one trip top to bottom expansion to form a lower end recess on a tubular is described using two swages of different dimensions. The smaller swage is run down hole with the larger swage behind it in a locked collapsed position. When the proper depth is reached the leading swage hits a no go. A pickup force with dogs engaged in a groove releases the lock on the larger swage at which point applied pressure sets an anchor, extends the larger swage to take over the expansion for the recess at the lower end of the tubular. An emergency release is provided to pull out of the hole if the swage cannot complete the task.

One trip tubular expansion and recess formation apparatus and method

Methods and devices for operation of a flapper valve. A valve assembly is described with a flapper element and a valve opening assembly that will mechanically open the flapper element. The valve opening assembly is particularly valuable where the flapper element fails to open in response to normal hydraulic opening techniques. The valve opening assembly includes a valve opening sleeve having a generally hemispherical cross-section and an opening portion that presents a pair of opening shoulders. The opening shoulders engage lugs on the flapper element so that movement of the opening sleeve will urge the flapper element to an open position. The valve assembly may be run into the wellbore with the flapper element in the open position, rather than having to be closed, as with a number of conventional valve assemblies.

Flapper opening mechanism

Devices and methods for fluid flow control within a production tubing string wherein a temporary flow blockage is established and selectively removed from the tubing string so that pressure testing or operation of a hydraulic tool within the string may be performed. A flow control device includes a housing that defines a flowbore therethrough with a restricted diameter portion. The restricted diameter portion presents a seating surface for a plug member and is provided by an annular shell that is shaped to project convexly inwardly. The shell may be fashioned of metal, elastomer or another suitable material, and it is capable of yielding to permit passage of a plug member upon application of a suitably great amount of fluid pressure. In operation, a plugging member is dropped in to the tubing string from the surface of the well and seats upon the seating surface. The tubing string is then pressured up to a first fluid pressure level for testing, tool operation, or the like, and the pressuring up will urge the plugging member against the plug seat in order to effect a fluid seal. When it is desired to remove the plugging member from the tubing string, and reestablish fluid flow through the tubing string, fluid pressure above the plugging member is raised to a second, overpressure level. The plug is then urged through the restricted diameter portion and expelled from the device to the wellbore sump below.

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Aberdeenshire, United Kingdom

Graham E Farquhar