Baker Hughes, a Ge Compnay, LLC

Baker Hughes Corporation

William Marsh Rice University

Baker Hughes Holdings LLC

Baker Hughes Oilfield Operations LLC

University of Houston System

Valery Khabashesku

Oleg Antonovych Mazyar

Oleksandr V Kuznetsov

Radhika Suresh

Sankaran Murugesan

Qusai Darugar

Devesh Kumar Agrawal

Darryl Ventura

Gaurav Agrawal

John L Margrave

Rostyslav Dolog

Mary Lou Margrave, Legal Representative

Haiqing Peng

Michael H Johnson

Othon Rego Monteiro

Vladimir P Filonenko

Soma Chakraborty

Enrique V Barrera

Juan Carlos Flores Perez

Yu Liu

Wilbur Edward Billups

Jiang Zhu

Yunming Ying

Toby D Hain

Anthony Albert DiGiovanni

Pulickel Madhavapanicker Ajayan

Nancy J Halas

Lei Zhang

John C Welch

Maxim Vasilyev

Bradley G Harrell

Mikhail Korjik

Rocco DiFoggio

D V Satyanarayana Gupta

Raouf Loutfy

Marc William Bird

Thomas McClain Scott

Juan Carlos Flores

Nicholas Carrejo

James Edward Goodson

Ramanan Krishnamoorti

Kevin Holmes

Toyli Anniyev

Zhenning Gu

Joshua C Falkner

Yash Parekh

Jong Dae Kim

Ashok Kumar Meiyazhagan

Alexander Moravsky

Qusai A Darugar

Andrey Federov

Ganguli Babu

Xiuli Wang

Andrei Fedorov

Gregor Chubaryan

Kristine N Ludwig

Valery A Davydov

Alexandra V Rakhmanina

Baburaj Eranezhuth

Zhou Zhou

Johm L Margrave

Valeri A Davydov

Keiko Kato

Rui Lobo

Daneesh McIntosh

Laura Peña-Paras

Stephen Mark Heath

Joel L Stevens

Gaelle Armelle Derrien

Valery Aleksandrovich Davydov

Aleksandra Viktorovna Rakhmanina

Lyudmile Stepanovna Kashevarova

John L Zimmerman

A downhole tool for controlling the flow of a fluid in a wellbore includes a component that comprises: a cementitious material; an aggregate; and a ductility modifying agent comprising one or more of the following: an ionomer; a functionalized filler; the functionalized filler comprising one or more of the following: functionalized carbon; functionalized clay; functionalized silica; functionalized alumina; functionalized zirconia; functionalized titanium dioxide; functionalized silsesquioxane; functionalized halloysite; or functionalized boron nitride; a metallic fiber; or a polymeric fiber.

Downhole tools containing ductile cementing materials

A method of forming a sand control device comprising: infusing a curable inorganic mixture with a degradable material configured to disintegrate upon exposure to an external stimuli; forming the curable inorganic mixture infused with the degradable material about a tubular; and curing the curable inorganic mixture infused with the degradable material.

Method of forming a sand control device from a curable inorganic mixture infused with degradable material and method of producing formation fluids through a sand control device formed from a curable inorganic mixture infused with degradable material

A method for producing fluorinated boron nitride involves heating a reactor chamber, providing boron nitride in the reactor chamber, flowing fluorine and an inert gas through the reactor chamber, and exposing the boron nitride to the flowing gases and the heat. The method may include boron nitride that is exfoliated or non-exfoliated. The fluorinated boron nitride that is produced from this method may have a hexagonal crystal structure or a cubic crystal structure. The method may additionally comprise removing the fluorinated boron nitride from the reactor chamber and mixing it with a surfactant. A suspension may comprise particles of fluorinated boron nitride suspended in a fluid, which may be polar or non-polar, and may additionally include a surfactant. The fluorinated boron nitride may have a hexagonal or a cubic crystal structure. Furthermore, the boron nitride may be exfoliated or non-exfoliated.

Direct gas fluorination of boron nitrides and compositions including fluorinated boron nitrides

A method of fracturing multiple productive zones of a subterranean formation penetrated by a wellbore is disclosed. The method comprises injecting a fracturing fluid into each of the multiple production zones at a pressure sufficient to enlarge or create fractures in the multiple productive zones, wherein the fracturing fluid comprises an upconverting nanoparticle that has a host material, a dopant, and a surface modification such that the upconverting nanoparticle is soluble or dispersible in water, a hydrocarbon oil, or a combination thereof; recovering a fluid from one or more of the multiple production zones; detecting the upconverting nanoparticle in the recovered fluid by exposing the recovered fluid to an excitation radiation having a monochromatic wavelength; and identifying the zone that produces the recovered fluid or monitoring an amount of water or oil in the produced fluid by measuring an optical property of the upconverting nanoparticle in the recovered fluid.

Upconverting nanoparticles as tracers for production and well monitoring

A method of reducing water saturation onto surfaces exposed to hydrocarbons during the production of hydrocarbons from subterranean formations by altering the wettability of the surface of the formation with surface modified nanoparticles.

Methods of altering the wettability of surfaces to enhance hydrocarbon production

A composition of matter includes a liquid and nanoparticles suspended in the liquid. The nanoparticles each include silica, alumina, and an organosilicon functional group having a molecular weight of at least 200. A method includes functionalizing a surface of nanoparticles with an organosilicon functional group and dispersing the nanoparticles in a liquid to form a suspension. The functional group has a molecular weight of at least 200. The nanoparticles each include silica and alumina at a surface thereof.

Methods including functionalizing nanoparticles and forming suspensions

A method of recovering hydrocarbons comprises introducing a suspension comprising nanoparticles to a material and contacting surfaces of the material with the suspension. After introducing the suspension comprising the nanoparticles to the material, the method further includes introducing at least one charged surfactant to the material and removing hydrocarbons from the material. Accordingly, in some embodiments, the nanoparticles may be introduced to the material prior to introduction of the surfactant to the material. Related methods of recovering hydrocarbons from a material are also disclosed.

Methods of recovering a hydrocarbon material

A method of analyzing a selected refinery chemical at a low concentration comprises contacting a sample with functionalized metallic nanoparticles that contain metallic nanoparticles functionalized with a functional group comprising a cyano group, a thiol group, a carboxyl group, an amino group, a boronic acid group, an aza group, an ether group, a hydroxyl group, or a combination comprising at least one of the foregoing; radiating the sample contacted with the functionalized metallic nanoparticles with electromagnetic radiation at a selected energy level; measuring a Raman spectrum emitted from the sample; and determining the presence or a concentration of a selected refinery chemical in the sample from the Raman spectrum.

Amine detection using surface enhanced Raman spectroscopy with functionalized nanoparticles

A method of making a thin film substrate involves exposing carbon nanostructures to a crosslinker to crosslink the carbon nanostructures. The crosslinked carbon nanostructures are recovered and disposed on a support substrate. A thin film substrate includes crosslinked carbon nanostructures on a support substrate. The crosslinked carbon nanostructures have a crosslinker between the carbon nanostructures. A method of performing surface enhanced Raman spectroscopy (SERS) on a SERS-active analyte involves providing a SERS-active analyte on such a thin film substrate, exposing the thin film substrate to Raman scattering, and detecting the SERS-active analyte.

Thin film substrates including crosslinked carbon nanostructures and related methods

A cyanide-functionalized gold nanoparticle. A method of making cyanide-functionalized gold nanoparticles includes forming an aqueous reaction mixture comprising a gold precursor and glycine, keeping the reaction mixture at about 18&#xb0; C. to about 50&#xb0; C. for at least 6 days to provide formation of the cyanide-functionalized gold nanoparticles, and isolating the cyanide-functionalized gold nanoparticles from the reaction mixture. A method of analyzing a sample, comprising contacting cyanide-functionalized gold nanoparticles with the sample and performing an analytical method on the sample. A sensor comprises cyanide-functionalized gold nanoparticles.

Process for making cyano functionalized gold nanoparticles

A method of stabilizing one or more clays within a subterranean formation comprises forming at least one treatment fluid comprising anionic silica particles, cationic silica particles, and at least one base material. The at least one treatment fluid is provided into a subterranean formation containing clay particles to attach at least a portion of the anionic silica particles and the cationic silica particles to surfaces of the clay particles and form stabilized clay particles. A method of treating one or more clays contained within a subterranean formation, and a treatment fluid for a subterranean formation.

Treatment fluids for a subterranean formation

A method of treating an elongated conductive element comprises exposing a conductive element sequentially to at least two dopants being different in composition. The dopants may include an acidic dopant and a halogen-based dopant. The conductive element comprises a plurality of carbon nanotubes and has a linear density in a range from about 0.1 tex to about 2.0 tex. The method further comprises mechanically densifying the conductive element. The elongated conductive element comprises at least one carbon nanotube fiber doped with a plurality of p-type dopants comprising at least one acidic dopant and at least one halogen-based dopant. The at least one carbon nanotube fiber has an electrical resistivity equal to or less than about 55 &#x3bc;&#x3a9;&#xb7;cm and an ultimate tensile strength equal to or greater than about 1 GPa.

Methods of treating carbon nanotubes and conductive elements including such carbon nanotubes

An energy storage device including a first electrode comprising lithium, a second electrode comprising a metal diboride, an electrolyte disposed between the first electrode and the second electrode and providing a conductive pathway for lithium ions to move to and from the first electrode and the second electrode, and a separator within the electrolyte and between the first electrode and the second electrode. A method of forming an energy storage device including forming a first electrode to include lithium, forming a second electrode to include a metal diboride, disposing an electrolyte between the first electrode and the second electrode, the electrolyte providing a conductive pathway for lithium ions to move to and from the first electrode and the second electrode, and disposing a separator within the electrolyte and between the first electrode and the second electrode.

Energy storage devices including at least one electrode comprising a metal diboride, and related methods

Growing community of inventors

Houston, TX, United States of America

Valery Khabashesku