Schlumberger Technology Corporation

Services Petroliers Schlumberger

Schlumberger Holdings Limited

Prad Research and Development Limited

Agathe Robisson

Partha Ganguly

Huilin Tu

Francois M Auzerais

Kuo-Chiang Chen

Murat Ocalan

Shitong Sherry Zhu

Julien Ramier

Yucun Lou

Meng Qu

Jahir A Pabon

Julio C Guerrero

Dominique Guillot

Sharath Chandra Mahavadi

Sandeep Verma

Nathan Wicks

Sudeep Maheshwari

Syed Afaq Ali

Mathew M Samuel

Nitin Y Vaidya

Sepand Ossia

Jeffrey E Thomas

Hossein Akbari

S Sherry Zhu

Olivier Sindt

Logan Munro

Simone Musso

Bruce Alexander Mackay

Roman Kats

Xiaoran Hu

Parthe Ganguly

Tu Huilin

Methods may include introducing a polymerizable composition containing a polycyclic monomer and a catalyst into a subterranean formation; and polymerizing the polymerizable composition in the presence of the catalyst in situ to form a polymer. Methods may also include lowering a wellbore tool into the subterranean formation, wherein the tool contains a first partition containing a polymerizable composition, and a second partition containing a catalyst; releasing the polymerizable composition from the first partition; releasing the catalyst from the second partition; contacting the polymerizable composition and the catalyst in a mixing region; and reacting the polymerizable composition and the catalyst in situ to form a polymer.

Methods for in situ formation of high glass transition temperature polymers

Methods include introducing a multistage treatment fluid into one or more intervals of a wellbore, wherein the treatment fluid contains one or more stages of a polymer-forming composition and one or more stages of a spacer fluid and initiating polymerization of the one or more stages of polymer-forming composition. Methods may include designing a multistage treatment fluid containing one or more stages of a polymer-forming composition and one or more stages of a spacer fluid, wherein or more stages of the polymer-forming composition comprises a thermosetting polymer; and pumping the multistage treatment fluid into a wellbore, wherein the pumping rate is determined by constructing a model based upon (a) the minimum pumping rate determined from the critical reaction temperature and the downhole temperature, (b) the fracture closing time, (c) the temperature within one or more fractures, and (d) the maximum pumping rate.

In situ solid organic pillar placement in fracture networks

Methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore comprising one or more stages of geopolymer precursor composition containing a geopolymer precursor and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition. In another aspect, methods of treating a subterranean formation penetrated by a wellbore may include injecting a multistage fracturing treatment into the wellbore that include one or more stages of geopolymer precursor composition, wherein the geopolymer precursor composition includes an emulsion having an oleaginous external phase, and an internal phase comprising one or more surfactants, a geopolymer precursor, and an activator, and one or more stages of a spacer fluid; and curing the one or more stages of geopolymer precursor composition.

In situ formed inorganic solids in fracture networks

Apparatus and methods for measuring confining pressure, axial strain and radial strain of zonal isolation materials are described. This information is useful for evaluating these materials and predicting seal performance and potential failures of these materials.

Confining pressure measurement for zonal isolation evaluation

A high temperature downhole packer including a tubular member, an annular and longitudinally movable ring, and a packer. The tubular member has a stop located on an outer diameter thereof. The annular and longitudinally movable ring is disposed around the outer diameter of the tubular member. The packer element is disposed between the stop and the ring. The packer element includes a high temperature elastomeric polymer having a first storage modulus from about 1,000 MPa to about 10,000 MPa at a first temperature between about &#x2212;100&#xb0; C. and about 175&#xb0; C., and a second storage modulus from about 1 MPa to about 1000 MPa at a second temperature ranging from about 175&#xb0; C. to about 475&#xb0; C.

Ultra high temperature packer by high-temperature elastomeric polymers

Certain embodiments described herein are directed to silane functionalized fillers that may be, for example, covalently coupled to a polymer. In some examples, devices that include the filler reinforced polymer compositions are also described.

Elastomer compositions with silane functionalized silica as reinforcing fillers

Certain embodiments described herein are directed to silane coupling agents that may be used, for example, to covalently couple a polymer to a filler. In some examples, devices that include the polymer-silane coupling agent-filler compositions are also described.

Coupling agents and compositions produced using them

Embodiments disclose a sand screen apparatus for use in a well that intersects a hydrocarbon formation. The sand screen apparatus comprises a composite, the composite having a compressed state and an expanded state. In embodiments, the composite comprises a base polymer and one or a plurality of reactive fillers where the reactive fillers react with the base polymer in the expanded state after exposure to a first trigger.

Compliant sand screen

An expandable structure for passive deployment in a well. The structure may be locked in a position determined by the inner dimensions of the well in which it is deployed. Practical uses for the structure may include production tubing or a host of other devices for affixing downhole with a final diameter as determined by the inner diameter of the well. Additionally, the structure may be configured for advancement to a targeted well location while in a collapsed state. Thus, upon deployment, subsequent structures may be advanced through the expanded/deployed structure. As such, affixed structures may be deployed downhole in both top-down and bottom-up fashions without concern over a prior deployed structure obstructing subsequent structure deployment downhole thereof.

Expandable structure for deployment in a well

Methods and related systems are described for controlling inflow of fluid into a production string. In aspects, the invention provides an inflow control device with a shut-off feature that is operated automatically utilizing swellable materials.

Utilizing swellable materials to control fluid flow

Apparatus and method comprising a plurality of particles which are magnetically attracted to one another in response to exposure to a magnetic field, and which maintain attraction to one another after removal of the magnetic field, the attraction being disabled when the particles are demagnetized, whereby the particles operate to alter the rheological properties of a fluid in which the particles are mixed when the attraction is enabled or disabled is disclosed.

Apparatus and method for treating a subterranean formation using diversion

A field-responsive fluid which enters a semi-solid state in the presence of an energy field is improved by use of a plurality of energy field responsive particles which form chains in response to the energy field. The particles can be (a) composite particles in which at least one field-responsive member having a first density is attached to at least one member having a second density that is lower than the first density, (b) shaped particles in which at least one field-responsive member has one or more inclusions, and (c) combinations thereof. The particles improve the field-responsive fluid by reducing density without eliminating field-responsive properties which afford utility. Further, a multi-phase base fluid including a mixture of two or more substances, at least two of which are immiscible, may be used. The multi-phase base fluid improves the field-responsive fluid because surface tension between the boundaries of the immiscible substances in conjunction with chains formed by field-responsive particles tends to stop or retard creep flow, resulting an improved dynamic or static seal.

Field-responsive fluids

The subject disclosure relates to apparatus and methods that are particularly suited for creating a seal in a borehole annulus. More particularly, the subject disclosure relates to a seal with enhanced sealing capability. In one embodiment the subject disclosure relates to a reinforced and permanent swellable packer device.

Oilfield apparatus and method comprising swellable elastomers

Cross-linkers and polymers produced using them are provided. The cross-linked polymers are suitable for use in applications where a broad temperature range may be encountered. In some examples, at least a first and a second polyetheretherketone chain may be cross-linked to each other through two or more Schiff base linkages. Articles using the cross-linked polymers are also described.

Growing community of inventors

Cambridge, MA, United States of America

Agathe Robisson