Schlumberger Technology Corporation

Meng Qu

Shitong Sherry Zhu

Yucun Lou

Francois M Auzerais

Agathe Robisson

Sharath Chandra Mahavadi

Sandeep Verma

Jahir A Pabon

Syed Afaq Ali

John David Rowatt

Sepand Ossia

Roman Kats

Miranda Amarante

Bruce Alexander Mackay

Matthew Godfrey

Xiaoran Hu

Philip Kokel

Gauri Joshi

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

Embodiments may generally take the form of a degradable composite structure and a method for controlling the rate of degradation of a degradable composite structure. An example embodiment may take the form of a degradable polymer matrix composite (PMC) including a matrix having: a degradable polymer, a fiber reinforcement, and particulate fillers. The fiber loading is between approximately 10% to 70% by weight and the particulate loading is between approximately 5% to 60%.

Degradable composite structures

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

Procedures include designing parameters for cementation jobs based upon the wellbore geometries and loading conditions. The cementation parameters such as Young's modulus are selected such that longitudinal crack propagation is inhibited. Procedures also include determining critical loading conditions for an already-cemented casing annulus based upon the specified cement properties and wellbore conditions. The critical loading conditions are determined such that longitudinal crack propagation in the cement is inhibited. Techniques are used to improve the friction coefficients between the casing and cement to inhibit longitudinal crack propagation. The treatments can include forming surface patterns that enhance friction and/or making the casing surface oleophopic and/or hydrophilic.

Inhibiting longitudinal propagation of cracks in wellbore cement

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Waltham, MA, United States of America

Meng Qu