Schlumberger Technology Corporation

Morphpackers Limited

Imperial Chemical Industries Limited

Meta Downhole Limited

Johnson Matthey Inc.

Schlumberger Technology Corpoation

Services Petroliers Schlumberger

Schlumberger B.v.

Peter Wood

Andrew John Gorrara

Daniel O'Brien

Patrick J Denny

William Luke McElligott

Neil Philip Thomson

David Glen Martin

Fraser Louden

Duncan James Trinder

Davidson Harman

Stuart Berry

Paul Hazel

Peter J Carnell

Cameron Hill Radtke

Peter John Herbert Carnell

Brian Peter Williams

Andrew John Joseph Gorrara

Kevin Stewart

Cathy Anne Woodroffe

Nicola Young

Peter John Carnell

Daniel O'brien

Neil Thomson

Daniel O'BRIEN

A technique facilitates anchoring between tubular structures in various well applications. The technique may utilize a load anchor having a radially expandable mandrel with an interior passage. Circumferential biasing members are mounted around the mandrel and each circumferential biasing member has a biasing surface. Additionally, a gripper system is positioned axially between the circumferential biasing members. The gripper system is configured such that engagement with the biasing surface of either circumferential biasing member causes radially outward biasing of the gripper system upon movement of the mandrel in either axial direction. A sealing element also may be disposed about the mandrel. The configuration of the gripper system and the circumferential biasing members protects the sealing element against undue axial movement once the load anchor is radially expanded into engagement with a surrounding surface.

Load anchor with sealing

A zonal isolation device in the form of an active external casing packer is provided which includes a tubular section such as a casing or liner and at least one sleeve member positioned on the exterior of the casing or liner and sealed thereto. The method detailed herein provides zonal isolation by use of a pair of spaced apart sleeve members during a frac operation where frac fluid is supplied to a zone (in between the pair of sleeve members) requiring to be frac'd, where the frac pressure acts not only on the outside of the zonal isolation device but also on the interior of the sleeve member to enhance the seal provided thereby.

Active external casing packer (ECP) for frac operations in oil and gas wells

A method and apparatus for creating a joint between tubulars such as tubing, pipes, casing and liner for location in a well bore. A connector () in the form of a sleeve is located over the ends of each tubular () and the ends of the tubulars are morphed onto the sleeve to provide a metal to metal seal. In an embodiment the sleeve () is morphed onto the ends of the tubulars (). The connector may also have a profiled inner surface with circumferential grooves () and a sectioned locating groove () to provide axial and torsional load bearing capacity.

Pipe joint

A coupling system between tubulars such as tubing, pipes, casing and liner for location in a well bore in which profiled sections () on the tubulars () are connected using a radially applied force to form a metal to metal sealed connection. Embodiments are provided in which the profiled sections are grooved and/or tapered, additional profiles are provided to prevent relative rotation of the tubulars, the radial force is applied inwardly, outwardly or in both directions, and a connector is used as an additional tubular member to form the coupling.

Pipe coupling

Apparatus and method for sealingly connecting tubular members in a wellbore. In a connector apparatus where a portion of a tubular member is radially expanded into sealing contact within a second tubular member, and the second tubular member has circumferential recesses on an inner surface, an annular resilient band member is arranged in the recesses. The annular resilient band member is acted on by the portion of the tubular member during expansion and maintains sealing contact to the portion after expansion.

Morphing tubulars

A morphable packer and method of setting the packer in a wellbore. The packer is a tubular member having a throughbore with a central portion having a greater diameter than each end portion with tapered portions there between. Gripping elements are arranged on the tapered portions. Morphing of the tubular member creates a seal between the central portion and an outer cylindrical structure, such as a wellbore or casing, and the gripping elements are moved radially outwards to engage with the cylindrical structure. The gripping elements act as slips which are activated by morphing the tubular member. Embodiments are described with the tubular member being a sleeve on a base pipe and, additionally, sealing and securing features in the form of elastomeric bands, lugs and wedges.

Packer

An assembly having a sleeve member located over a tubular body, there being a chamber between the two and by increased pressure in the chamber the sleeve member is morphed to secure it to a well bore wall and create a seal between the sleeve and well bore wall to form an isolation barrier. The tubular body is formed in one or more sections so that annular planar faces are created for abutment between the sleeve member and the tubular body so as to remove the requirement for complex fittings and reduce the time of construction.

Isolation barrier

A tubular portion apparatus () to be secured and sealed to another tubular () is described as is a method of securing and sealing a tubular portion () to an existing downhole tubular () such as a casing string (). The tubular portion () comprises a central portion (), an upper () and a lower () portion adjacent to the central portion () along a longitudinal axis of the tubular portion (). The tubular portion () is formed from a main material and an additional material to strengthen the upper () and the lower () portion of the tubular portion ().

Apparatus and a method for securing and sealing a tubular portion to another tubular

A tubular assembly is disclosed for use in a wellbore () of an oil, gas or water well, typically for landing a downhole device in the wellbore. The assembly has a sleeve () adapted to receive the body of the downhole device. The sleeve is deployed into a conduit in the wellbore and expanded, so that the outer circumferential surface of the sleeve is radially expanded against the inner surface of the conduit. The sleeve has a bore with an inner circumferential surface comprising an inwardly facing formation adapted to engage with an outwardly facing formation on the body of the downhole device when the body of the downhole device is disposed in the bore of the sleeve. The sleeve is typically deployed in the wellbore at the desired location and is radially expanded by an expander device () that is deployed within the bore of the sleeve. The expanded sleeve plastically deforms and retains its expanded configuration after the radial expansion force is removed from the sleeve. The sleeve provides a modular anchoring or landing point in the wellbore that can be retrospectively set in the conduit at different locations, and various downhole devices can then be deployed into the sleeves at predictable depths and a reliable connection can be made with the sleeve. The assembly can typically pass through a smaller diameter before being morphed to seal and anchor in a larger diameter.

Tubular assembly and method of deploying a downhole device using a tubular assembly

An apparatus () and method, particularly useful for isolating zones in a hydrocarbon open hole well bore (). The apparatus includes a tubular body (), arranged to be run into and secured within the well bore. A sleeve member () is positioned on the exterior of the body and is sealed thereto creating a chamber () therebetween. Pressure is applied through a port () in the body to cause the sleeve member to move outwardly and morph to an inner wall of the well bore. Pressure is trapped in the chamber and maintained at a morphed pressure value by pressure balancing means in the form of a biased piston ().

An apparatus and method for providing a tubular connection in the form of a liner tieback connection or a liner hanger in a slim hole well as found in deep wells. When installing the casing sections, a first casing section having a profiled surface distinct from a surface of an adjacent casing section is provided. A liner is run into the first casing section and a part of a portion is radially expanded to morph against the inner surface of the first casing section at the profiled surface and form a sealed joint. Various arrangements of profiled surfaces are provided. The liner may also have a profiled surface. By adapting the casing section to receive the liner directly, a slim hole well construction is achieved.

Apparatus and method for use in slim hole wells

A zonal isolation device () in the form of an active external casing packer is provided which includes a tubular section such as a casing or liner () arranged to be run into and secured within a larger diameter generally cylindrical structure such as an open borehole (). At least one sleeve member () is positioned on the exterior of the casing or liner and is sealed thereto and at least two deformable band members () are provided around and are bonded to the outer circumference of the sleeve member. The sleeve member and the at least two deformable band members is/are expanded into place against the inner circumference of the open borehole by increasing the pressure within the sleeve member. The method detailed herein also provides zonal isolation by use of a pair of spaced apart members during a frac operation where frac fluid is supplied to a zone (in between the pair of sleeve members) requiring to be frac'd, where the frac pressure acts not only on the outside of the zonal isolation device but also on the interior of the sleeve member to enhance the seal provided thereby.

A method of connecting a first tubular member to a second tubular member located in a wellbore, the second tubular member including an upper end portion which has a greater diameter than the diameter of the first tubular member, the method comprising: lowering the first tubular member into the wellbore until the first tubular member is located at least within the bore of the upper end portion of the second tubular member; and expanding the first tubular member until the first tubular member is sealingly connected to the second tubular member.

Expandable liner tieback connection

A downhole expandable liner hanger apparatus for extending the length of an existing tubular such as a casing or liner string is described. The apparatus comprises a tubular portion and a securing and/or sealing means for securing the tubular portion to the existing tubular such as a casing string to thereby extend the length of the existing tubular and preferably simultaneously provide a sealed coupling between the tubular portion and the existing tubular. A first part or a length of the tubular portion preferably comprises a first sidewall thickness and a second part or length of the tubular portion is located adjacent the first part, where the second part comprises a second sidewall thickness, said first sidewall thickness being less than the second sidewall thickness.

Expandable liner hanger

A method of making a sulphided ion exchange resin from an ion exchange resin containing primary or secondary amino group comprises passing a non-aqueous liquid, e.g. a hydrocarbon, feedstock containing elemental sulphur or organic, or inorganic, di-or poly-sulphides through a bed of an ion exchange resin containing primary or secondary amino groups, and so unsulphided ion exchange resins containing primary or secondary amine groups may be used to remove such elemental sulphur or sulphur compounds from liquid, e.g. hydrocarbon, feedstocks. The sulphided ion exchange resins may be used to remove elemental mercury or organic mercury compounds from liquid, e.g. hydrocarbon, streams.

Growing community of inventors

Aberdeen, United Kingdom

Peter Wood