Schlumberger Technology Corporation

William Marsh Rice University

Ykk Corporation

James Friedheim

Steven Philip Young

Robert Bailey

Chemsseddine Bouguetta

Roger Wayne Matlock

Henry Lee Conn

Brandi Katherine Price Hoelscher

Guido De Stefano

James Mitchell Tour

Arvind D Patel

Wei Lu

Quanxin Guo

John Moffitt

Cara Bovet

Joshua Sheldon

Bostjan Genorio

Guido Destefano

Katherine Price Hoelscher

A method of sealing a formation that includes drilling a wellbore through the formation while pumping a non-aqueous based wellbore fluid comprising a first sealing component into the wellbore, wherein the non-aqueous based wellbore fluid filters into the formation as a filtrate and substantially thickens is disclosed. The substantially thickening may result from adding a second sealing component to the wellbore fluid, whereby the first sealing component initiates a reaction of the second sealing component.

Smart filtrate for strengthening formations

Fluid compositions including a base fluid and at least one granular hemicellulose material. The base fluid may be an oleaginous fluid or a non-oleaginous fluid. The granular hemicellulose material may have a cumulative particle size distribution D90 of about 4 mm or less and D10 of about 1 mm or greater, or D90 of 2.5 mm or less and D10 of about 1.5 mm or greater, or even D90 of about 3.8 mm or less, and D10 of about 2.4 mm or greater. The granular hemicellulose materials useful may have an average aspect ratio equal to or less than about 5:1, an average aspect ratio equal to or less than about 2:1, or even an average aspect ratio is about 1:1. The granular hemicellulose materials have hemicellulose in an amount from about 10% to about 50% by weight, cellulose in an amount from about 30% to about 50% by weight, and lignin in an amount from about 5% to about 35% by weight. The granular hemicellulose materials may be added to the base fluid in an amount from about 1 ppb to about 50 ppb, or even from about 4 ppb to about 40 ppb. The fluid compositions may be useful for sealing fractures in a subterranean formation, and reducing fluid loss in a subterranean formation.

Lost circulation material

Electrically conductive oil-based wellbore fluids and methods of using same are provided. Wellbore fluids provided may contain one or more carbon nanotubes, where the one or more carbon nanotubes have a particular d/g ratio as determined by Raman spectroscopy. Also provided are methods for electrical logging of a subterranean well that include emplacing a logging medium into a subterranean well, wherein the logging medium contains a non-aqueous fluid and one or more carbon nanotubes, where the one or more carbon nanotubes are present in a concentration so as to permit the electrical logging of the subterranean well; and acquiring an electrical log the subterranean well.

Electrically conductive wellbore fluids and methods of use

A wellbore fluid may include a base fluid, and a ground weight material comprising barite and quartz and having a dbetween about 4 and 8 microns and a dbetween about 15-25 microns. The ground weight material of the wellbore fluid may have a specific gravity of less than or equal to about 4.2.

Wellbore fluids for use downhole

A method of sealing a formation that includes drilling a wellbore through the formation while pumping a non-aqueous based wellbore fluid comprising an encapsulated first component into the wellbore, the non-aqueous based wellbore fluid forming a filter cake on the walls of the wellbore; and adding a second component to the wellbore fluid when fluid losses are registered during drilling, whereby the first and second components react to form a chemical sealing layer in the filter cake is disclosed.

Smart filter cake for strengthening formations

A wellbore fluid may include an oleaginous continuous phase, one or more magnetic carbon nanoribbons, and at least one weighting agent. A method of performing wellbore operations may include circulating a wellbore fluid comprising a magnetic carbon nanoribbon composition and a base fluid through a wellbore. A method for electrical logging of a subterranean well may include placing into the subterranean well a logging medium, wherein the logging medium comprises a non-aqueous fluid and one or more magnetic carbon nanoribbons, wherein the one or more magnetic carbon nanoribbons are present in a concentration so as to permit the electrical logging of the subterranean well; and acquiring an electrical log of the subterranean well.

Wellbore fluids incorporating magnetic carbon nanoribbons and magnetic functionalized carbon nanoribbons and methods of using the same

A method for transferring barite for use in wellbore fluids may include providing a ground weight material comprising barite and quartz having a dbetween about 4 and 8 and a dbetween about 15-25 microns to a pneumatic transfer vessel, supplying an air flow to the ground weight material in the pneumatic transfer vessel, and pneumatically transferring the ground weight material from the pneumatic transfer vessel to a storage vessel.

Methods of pneumatically conveying solid particulates

A method of drilling a subterranean well may include drilling the subterranean well while circulating a wellbore fluid in the subterranean well, wherein the wellbore fluid includes a base fluid; and a ground weight material comprising barite and quartz and having a dbetween about 4 and 8 microns and a dbetween about 15-25 microns.

Methods of drilling

A method of triggering heating within a subterranean formation, that includes introducting a wellbore fluid containing a dispersed carbon nanomaterial into a wellbore through the subterranean formation; lowering a microwave or ultraviolet radiation source into the wellbore; and irradiating the wellbore with microwave or ultraviolet radiation, thereby increasing the temperature of the wellbore fluid and/or wellbore is disclosed.

Growing community of inventors

Spring, TX, United States of America

James Friedheim