Baker Hughes Corporation

Baker Hughes, a Ge Compnay, LLC

Fmc Technologies, Inc.

Kushal Seth

James B Crews

Tianping Huang

Allen Dale Gabrysch

John Robert Willingham

Richard Mitchell

Zhiyue Xu

Gaurav Agrawal

Soma Chakraborty

Larry Hines

Thomas Krebs

Govert L Kruijtzer

Brian A Evans

Sergio Arreola, Jr

Jenifer C Lascano

Gregory A Caraway

Eduardo Candia

Allen Grabrysch

Paulus Henricus Joannes Verbeek

Clint G Todd

Kelly P Ciprick

Suman Kalyan Hajra

A wastewater treatment system is disclosed that includes a desanding hydrocyclone, a deoiling hydrocyclone, an electrocoagulation apparatus that is adapted to receive a flow of treated wastewater from the desanding and deoiling hydrocyclones, a floc separator that is adapted to receive a flow of a first effluent from the electrocoagulation apparatus, and an ultrafiltration membrane apparatus that is adapted to receive at least a portion of a flow of a second effluent from the floc separator.

Systems and methods for treating oilfield wastewater

A process for treating oilfield waste water includes combining oilfield waste water and a biocide comprising hydrogen peroxide, the biocide being present in an amount effective to decrease a number density of bacteria in the oilfield waste water. The treated water can be reused in a subterranean environment.

Treating and recylcing oilfield waste water

A method for reducing sulfide in oilfield waste water includes contacting oilfield waste water with an oxidizer in the presence of an iron catalyst. The oilfield waste water includes sulfide that is oxidized to sulfate while avoiding formation of a colloidal or bulk sulfur precipitate. A method for recycling oilfield waste water includes contacting oilfield waste water with an oxidizer in the presence of an iron catalyst, the oilfield waste water comprising sulfide; oxidizing the sulfide to sulfate; avoiding formation of a colloidal sulfur precipitate, a bulk sulfur precipitate, or a combination comprising at least one of the foregoing; clarifying the oilfield waste water by contacting the oilfield waste water with a flocculant to form an aggregate precipitate; separating the aggregate precipitate from the oilfield waste water to form a recycled water; combining an additive with the recycled water; and disposing the recycled water in a downhole environment.

Composition and method for treating oilfield water

Introducing a fluid composition and a heat-generating fluid into a wellbore may improve timing and/or conditions of generating in situ heat downhole. The generated heat may be used to melt wax, and dissolve paraffins and asphaltenes or other deposits within the wellbore or in the reservoir itself. The fluid composition may include a base fluid and a metallic powder having a plurality of metallic powder particles. The base fluid may be or include a drilling fluid, a completion fluid, a stimulation fluid, a workover fluid, an activation fluid, and mixtures thereof. Each metallic powder particle may have a metallic particle core, and a coating disposed on the metallic particle core having a coating material. The metallic particle core may be released from the metallic powder particle. A heat-generating fluid may contact the released metallic particle core and thereby generate heat.

In situ heat generation

In aspects, the disclosure provides a method for cementing a borehole that includes selecting a location in the borehole for cementing. The method further includes providing a cement slurry comprising a cement and shape memory members having a first shape, the shape memory members configured to expand from the first shape to a second shape upon application of heat to the shape memory members, placing the cement slurry in the selected space and heating the shape memory members in the selected space to attain the second shape.

Apparatus and method for cementing a borehole

A method of mitigating corrosion of downhole articles includes mixing a plurality of nanoparticles into a first downhole fluid to form a nanoparticle fluid. The method also includes exposing a surface of a downhole article in a wellbore to the nanoparticle fluid. The method further includes disposing a barrier layer comprising a portion of the nanoparticles on the surface of the article and exposing the surface of the downhole article to a second downhole fluid, wherein the barrier layer is disposed between the second downhole fluid and the surface of the article.

Method of corrosion mitigation using nanoparticle additives

Emulsified acids have been used to increase production rates of oil and gas in carbonate reservoirs through acid fracturing and matrix acidizing operations. An emulsifier is used to emulsify the aqueous acid with an oil, usually diesel. Very small particles, such as colloidal clay particles and/or nanoparticles increase the stability of the emulsified acids over an elevated temperature range.

Stabilizing emulsified acids for carbonate acidizing

Using a complex emulsion for treating a subterranean formation, such as to dissolve minerals therein (e.g. carbonates, scales, and/or filter cake) to improve permeability, substantially improves post treatment fluid clean-up for improved hydrocarbon production. The complex emulsion is made by mixing an acid aqueous phase with an oil external microemulsion to give an initial product, where the acid aqueous phase is an external phase and the microemulsion is an internal phase. Then the initial product is mixed with a second oil (e.g. xylene, diesel, toluene, kerosene, other aromatics, refined hydrocarbons and the like) containing an emulsifier to make a complex emulsion.

Method for improving the clean-up of emulsified acid fluid systems

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Houston, TX, United States of America

Kushal Seth