Baker Hughes, a Ge Compnay, LLC

Baker Hughes Holdings LLC

Baker Hughes Corporation

Bakers Hughes Inc.

Prasad D Dhulipala

Charles David Armstrong

C David Armstrong

Qi Qu

Soma Chakraborty

Sunder Ramachandran

Jeffrey Russek

Jack Lynn

Charles D Armstrong

Zhengwei Liu

Sankaran Murugesan

Corrosion and/or calcium scale deposition on a surface in contact with corrosion forming components and/or scale forming components within a subterranean formation may be decreased, prevented, and/or inhibited by contacting the surface with at least one protein. The protein(s) may be or include, but is not limited to, at least one aspein protein, at least one aspolin protein, at least one dentine protein, at least one DRICH-1 protein, at least one nacrein protein, at least one SMDT-1 protein, derivatives thereof, fragments thereof, mimetics thereof, and combinations thereof. The surface may be or include, but is not limited to a metal surface, a plastic surface, a ceramic surface, a painted surface, a coated surface, and combinations thereof.

Decreasing foulant deposition on at least one surface by contacting the surface(s) with at least one protein

Proteins with antibacterial properties may be used in additive compositions, fluid compositions, and methods for decreasing or removing sulfur-containing compounds and/or acid-containing compounds from recovered downhole fluids and/or the subterranean reservoir wellbore from which the downhole fluid was recovered. The fluid composition may include at least protein and a base fluid. The protein(s) may be or include a labiase, a lysozyme, a lysostaphin, a hexose oxidase, a cecropin, a thermolysin, a serine protease, a cysteine protease, and combinations thereof. The base fluid may be or include a drilling fluid, a servicing fluid, a production fluid, a completion fluid, an injection fluid, a refinery fluids, and combinations thereof.

Proteins for removing sulfurous compounds and/or acidic compounds in downhole fluids

A method of reducing an amount of a sulfur-containing compound in a reservoir fluid includes contacting a treatment fluid comprising an aqueous medium and an enzymatic scavenger with a precipitating fluid to precipitate the enzymatic scavenger; contacting the precipitated enzymatic scavenger with the reservoir fluid comprising the sulfur-containing compound; and reducing a number of the sulfur-containing compound in the reservoir fluid.

In-situ hydrogen sulfide mitigation

A treatment method for a hydrocarbon well includes placing a well treatment fluid containing a viscosifying agent in the well and, using the viscosifying agent, attaining a first viscosity of the fluid in the well. The method includes combining a porphyrin compound with the fluid and, using the porphyrin compound, decreasing viscosity of the fluid in the well to a second viscosity less than the first viscosity. A hydrocarbon well treatment fluid includes an aqueous carrier fluid, a polymer viscosifying agent, and a chlorophyll compound.

Hydrocarbon well treatment methods and fluids

Cysteine synthase or O-Acetyl-L-Serine Sulfhydrylase enzymes, such as those derived from thebacterium, may be used in additive compositions, fluid compositions, and methods for decreasing or removing hydrogen sulfide from recovered downhole fluids and/or the subterranean reservoir wellbore from which the downhole fluid was recovered. The fluid composition may include at least one cysteine synthase enzyme and a base fluid, such as a drilling fluid, a servicing fluid, a production fluid, a completion fluid, an injection fluid, a refinery fluids, and combinations thereof.

Enzymes for removing sulfurous compounds in downhole fluids

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Katy, TX, United States of America

Prasad D Dhulipala