William Marsh Rice University

Bp Corporation North America Inc.

Ykk Corporation

Jim Friedheim

Arvind D Patel

Emanuel Stamatakis

Eric James Davis

Steve Young

Sashikumar Mettath

James Mitchell Tour

Mark E Sanders

Mark William Alberty

Randall Vashishta Sant

Mark Shelton Aston

Burhan Hoxha

Cara Bovet

Ruquan Ye

John Candler

Reginald Bell

Stephen Rabke

Gabriel Ceriotti

Alexander Slesarev

John Lee

Burnham Hoxha

Katherine Price-Hoelscher

Various embodiments of the present disclosure provide methods of making wellbore fluids with enhanced electrical conductivities. In some embodiments, such methods comprise: (1) pre-treating a carbon material with an acid; and (2) adding the carbon material to the wellbore fluid. Further embodiments of the present disclosure pertain to wellbore fluids formed by the methods of the present disclosure. Additional embodiments of the present disclosure pertain to methods for logging a subterranean well by utilizing the aforementioned wellbore fluids.

Carbonaceous nanoparticles as conductivity enhancement additives to water-in-oil emulsions, oil-in-water emulsions and oil-based wellbore fluids

A method of increasing the fracture resistance of a low permeability formation that includes emplacing a wellbore fluid in a wellbore through the low permeability formation, the wellbore fluid comprising: a settable carrier fluid; and a solid particulate bridging material; increasing the pressure in the wellbore such that fractures are formed in the formation; allowing the settable carrier fluid to enter the fractures; bridging and sealing the mouths of the fractures to form a substantially impermeable bridge proximate the mouth of the fractures thereby strengthening the formation; and holding the increased pressure for an amount of time sufficient for setting of the carrier fluid in the fractures is disclosed.

Methods of increasing fracture resistance in low permeability formations

A composition that includes a product resulting from a condensation reaction of quebracho with at least one organophilic species that includes a reactive amine is disclosed.

Fluid loss additive for oil-based muds

A drilling fluid having an oleaginous fluid that forms the continuous phase; a non-oleaginous fluid, which is the discontinuous phase; a primary emulsifier in sufficient concentration to stabilize the invert emulsion; and a rheology modifier, which serves to moderate the rheology change across a temperature range of 40 to 150&#xb0; C. The rheology modifier may be a dimer poly-carboxylic Cto Cfatty acid, trimer poly-carboxylic Cto Cfatty acid, tetramer poly-carboxylic Cto Cfatty acid, mixtures of these acids, or a polyamide wherein the polyamide is the condensation reaction product of a C-Cfatty acid and a polyamine selected from the group consisting of diethylenetriamine, triethylenetetramine; and pentaethylenetetramine. The drilling fluid preferably includes a weighting agent or bridging agent which may be selected from galena, hematite, magnetite, iron oxides, illmenite, barite, siderite, celestite, dolomite, calcite as well as combinations and mixtures of these and similar compounds. Optionally organophillic clay, fluid loss agents, alkali reserve materials, and other conventional invert emulsion drilling fluid components may be added to the drilling fluid.

Flat rheology drilling fluid

A water-base fluid for use in drilling wells and other drilling operation includes a shale clay which swells in the presence of water. The fluid preferably includes: an aqueous based continuous phase, and a shale hydration inhibition agent having the formula:H&#x2014;(OR)&#x2014;[&#x2014;NH&#x2014;CH&#x2014;CH&#x2014;CH&#x2014;O&#x2014;CH&#x2014;CH&#x2014;NH&#x2014;]&#x2014;(R'O)&#x2014;H

High performance water based drilling fluids and method of use

A water-base fluid for use in drilling, cementing, workover, fracturing and abandonment of subterranean wells through a formation containing a shale which swells in the presence of water. In one illustrative embodiment, the drilling fluid includes, an aqueous based continuous phase, a weighting agent, and a shale hydration inhibition agent. The shale hydration inhibition agent should have the general formula:  in which A is independently selected from H and CHCHCHNH; and in which B is independently selected from H, CHCHOH, CHCHOCHCHCHNHand CHCHCHNH. The shale hydration inhibition agent is present in sufficient concentration to substantially reduce the swelling of shale drilling cuttings upon contact with the drilling fluid. The drilling fluid may be formulated to include a wide variety of components of aqueous based drilling fluids, such as weighting agents, fluid loss control agents, suspending agents, viscosifying agents, rheology control agents, as well as other compounds and materials known to one of skill in the art. The fluids may also be used in the disposal by reinjection of drilling cutting into a selected subterranean disposal formation.

Shale hydration inhibition agent and method of use

A method of formulating and the resulting biodegradable wellbore fluid includes a first synthetic internal olefin fraction having from 16 to 18 carbon atoms (CIO), a second synthetic internal olefin fraction having between 15 to 18 carbon atoms (CIO), and a third synthetic internal olefin fraction having 15 to 16 carbon atoms (CIO). The components of the wellbore fluid are blended such that the desired characteristics of polycyclic aromatic hydrocarbon content, toxicity and biodegrability are balance to achieve compliance with environmental requirements for hydrocarbon based drilling fluids. One such illustrative embodiment achieves this result by utilizing a formulation in which the first internal olefin fraction is present in a range of about 45 to about 55 percent by weight of the wellbore fluid and wherein the second internal olefin fraction is present in range of about 20 to about 30 percent by weight of the wellbore fluid and wherein the third olefin fraction is present in range of about 20 to about 30 percent by weight of the wellbore fluid. Optionally, the illustrative fluid can include a Calpha olefin (CAO). In such instances, the Calpha olefin (CAO) is present in the range of about 10 to about 20 percent by weight of the wellbore fluid.

Environmentally compatible hydrocarbon blend drilling fluid

High performance water based drilling mud and method of use

Oil based well fluids with high solids content

An invert emulsion suitable for drilling subterranean wells, in particular oil and gas wells is disclosed which has negative alkalinity and includes an oleaginous phase, and a non-oleaginous phase and an emulsifying agent which stabilizes the invert emulsion under conditions of negative alkalinity. The practice of the present invention permits the formulation of drilling fluids which are absent an alkaline reserve and are compatible with elastomers utilized in drilling equipment. Thus the invert emulsion fluids of the present invention are highly suitable for drilling oil and gas wells.

Invert emulsion drilling fluids and muds having negative alkalinity and elastomer compatibility

Growing community of inventors

Spring, TX, United States of America

Jim Friedheim