Schlumberger Technology Corporation

Drillflex

Schlumberger Canada Limited

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Pierre-Yves Corre

Stephane Metayer

Jean-Louis Pessin

Alexander F Zazovsky

Stephen Yeldell

Julian J Pop

Stephane Briquet

Gilles Carree

Philippe Hocquet

Carsten Sonne

Kathiravane Tingat Cody

Edward Harrigan

James Leighton

Adriaan Gisolf

Cosan Ayan

Jean-Louis Saltel

Ashers Partouche

Nathan Mathew Landsiedel

Sebastien Ives

David Milton Eslinger

John R Lovell

Sylvain Bedouet

Anthony R H Goodwin

Vladimir Vaynshteyn

Frank F Espinosa

Colin Allan Wilson

John E Edwards

Nitin Y Vaidya

Anthony Robert Holmes Goodwin

Hadrien Dumont

Claude J Vercaemer

Zheng Rong Xu

Ramon Hernandez-Marti

Guillaume Boutillon

Hugues Dupont

Patrice Milh

Henri-Pierre Valero

Lambert Rouchon

Stéphane Metayer

Chen Tao

Francois Xavier Dubost

German Garcia

Beatriz E Barbosa

Baptiste Germond

Bertrand Claude Theuveny

Morten Kristensen

Darya Aleksandrovna Mustafina

Zeynep Alpman

Barry Nicholson

Nicholas Ellson

Thomas Berard

Francois Chevillard

Magdy Samir Osman

Ronan Le Gloahec

Emma Ford

Alejandro Martinez Pereira

Catrina De Matos

George Christopher Tevis

Pierre Clery

Miroslav Slapal

Jean Louis Saltel

Rania El Fadil

Julien Lassalle

Jason Hueber

Anthony Rh Goodwin

A device may expand a first packer against a borehole wall. A device may expand a second packer against the borehole wall. A device may expand a third packer against the borehole wall. A device may expand a fourth packer against the borehole wall. A device may pressurize an interior zone longitudinally between the second packer and the third packer to a first pressure relative to a hydrostatic borehole pressure that is greater than a second pressure of at least one exterior zone, wherein a first exterior zone is longitudinally between the first packer and the second packer and a second exterior zone is longitudinally between the third packer and fourth packer.

Systems and methods for surface supervision of a downhole tool

The disclosure relates to a cable () comprising a core () and a plurality of reinforcing elements () arranged around the core () so as to cover the core (), wherein each reinforcing element () includes at least a bundle of reinforcement fibers comprising at least one fiber and a thermoset matrix impregnating the bundle of fibers, wherein each reinforcing element () is individually tubed with a thermoplastic coating ().

Cable, in particular for downhole use, and method of manufacturing such cable

Systems and methods presented herein provide for the generation of acoustic waves for acoustic stimulation, as well as for analysis of subterranean formations, using downhole tools and associated equipment that are not conventionally designed to do so. For example, in certain embodiments, formation testing tools, formation, measurement tools, inflatable packers, and so forth, may be controlled by control systems to, for example, create pressure pulses that generate the acoustic waves. In addition, in certain embodiments, a tool conveyance system that conveys a formation testing or measurement tool into a wellbore may include acoustic receivers that may detect the acoustic waves after they reflect from subterranean features of the formation.

Downhole acoustic wave generation systems and methods

A method can include flowing fluid from a formation from an inlet of a tool to an annulus; flowing spacer fluid from a conduit to the annulus; flowing the fluid and the spacer fluid in the annulus to a station; and collecting the fluid.

Geologic formation characterization via fluid separation

The disclosure relates to a method of evaluating characteristics of an earth formation, comprising deploying a packer assembly in a borehole penetrating an earth formation, the packer assembly comprising an instrumented inflatable packer element including fiber optic sensors; inflating the instrumented inflatable packer elements; detecting, using the fiber optic sensors, events occurring in the earth formation; and transmitting data corresponding to the detected events to a surface processing system. The disclosure also relates to a packer element and a instrumented packer assembly system. The disclosure may enable to derive formation characteristic in several configurations such as a stress test or a hydraulic fracturing configuration.

Instrumented packer having distributed fiber optic sensor

Aspects of the present disclosure relate to an expandable packer assembly that includes a mechanical flow assembly. In some embodiments, the mechanical flow assembly includes a fluid arm that directs a flow of fluid into an expandable element to inflate the expandable element, and a support arm that provides support to the fluid arm during inflation of the expandable element. In some embodiments, the mechanical flow assembly is rotatably coupled to a piston and a packer conduit of the expandable element via linkages.

Mechanical flow assembly

An inflatable packer assembly comprising a first fixed sleeve fixed to a mandrel, a first sliding sleeve moveable along the mandrel, and a first inflatable member connected to the first fixed sleeve and the first sliding sleeve. A second sliding sleeve is moveable along the mandrel, and a second inflatable member is connected to the first sliding sleeve and the second sliding sleeve. A second fixed sleeve is fixed to the mandrel and slidably engages the second sliding sleeve. An inflation flowline disposed within the mandrel is in fluid communication with interiors of the first and second inflatable members for inflating the first and second inflatable members to isolate a portion of a wellbore penetrating a subterranean formation. An injection flowline is disposed within the mandrel for injecting a fluid into the isolated wellbore portion at a high enough pressure to create microfractures in the subterranean formation.

Stress testing with inflatable packer assembly

The present disclosure relates to a downhole packer assembly that includes an outer skin, an inner packer disposed within the outer skin such that inflation of the inner packer is configured to expand the outer skin, a pair of mechanical fittings engaged with axial ends of the outer skin, and a ring assembly disposed within at least one of the pair of mechanical fittings. The ring assembly includes a shear pin configured to shear upon application of a tensile force to the downhole packer assembly.

Systems and methods for an expandable packer

The present disclosure relates to a system that includes a downhole packer assembly that includes an outer skin having a first axial length and an inner packer having a second axial length greater than the first axial length. The inner packer is disposed within the outer skin such that inflation of the inner packer causes the outer skin to expand.

The present disclosure relates to a downhole packer assembly that includes an outer skin, an inner packer disposed within the outer skin such that inflation of the inner packer is configured to expand the outer skin, an end support coupled to an outer skin end and an inner packer end, a retraction assembly coupled to the end support via a plurality of connecting members, and a plurality of chambers disposed within the retraction assembly. The plurality of connecting members are at least partially disposed within the plurality of chambers.

Systems and methods for retraction assembly

A system includes a formation sampling tool having a body, a probe shoe extendibly mounted to the body, a packer coupled to the probe shoe, and an inlet fixedly coupled to the probe shoe and the packer. The packer surrounds the inlet and the inlet includes an anti-extrusion ring extending beyond an outer surface of the packer. The system also includes a filter disposed within the inlet.

Systems and methods for formation sampling

The present disclosure relates to a downhole packer assembly that includes an outer skin, an inner packer disposed within the outer skin such that inflation of the inner packer is configured to expand the outer skin, and a flexible flowline at least partially embedded within the outer skin. The flexible flowline is configured to flex as the outer skin expands.

In one example a tool is provided, having a body configured to expand from a first diameter to a second diameter, an outer covering for the body, the outer surface having at least one inlet to accept fluid through the outer covering into the body, the outer covering to outer proximate ends and at least two anti-creep rings abutting the outer covering at each of the outer proximate ends, wherein the anti-creep rings constrain the outer covering from movement.

Anti-creep rings and configurations for single packers

A packer assembly has an inner expandable packer. An outer layer having sealing bodies may be disposed about and/or positioned on the outer surface of the inner expandable packer member. Each of the sealing bodies may have an elastomeric body, and one or more flowlines may be embedded in the elastomeric body of each of the sealing bodies. The sealing bodies may be located in grooves in the inner expendable packer member. The sealing bodies may contact a surrounding casing or a surrounding formation to form an annular seal; in an embodiment, the sealing bodies and the inner expandable packer member may contact a surrounding casing or a surrounding formation to form an annular seal. The sealing bodies may be non-integral with each other and/or separable from each other.

Packer assembly with sealing bodies

A technique involves a packer formed as an expandable packer with an internal expandable bladder. The expandable bladder is formed with a section that is radially enlarged relative to an axial end of the expandable bladder when the bladder is in a relaxed state. The bladder configuration enables use of a reduced expansion ratio while still allowing expansion of the packer to a desired large diameter.

Expandable packer methods

Growing community of inventors

Eu, France

Pierre-Yves Corre