Baker Hughes, a Ge Compnay, LLC

Baker Hughes Corporation

Baker Hughes Holdings LLC

Charles David Armstrong

Qi Qu

Mark Alan Vorderbruggen

Prasad D Dhulipala

Stanley Gunawan

Michael Brendt Wilson

Frances H Debenedictis

Brandon M Vittur

Rupa Venugopal

Marshall G Ault

Mark A Vorderbruggen

Harold Dean Brannon

Hoang Van Le

Lawrence N Kremer

Crystal Lee

Bharath Rajappa

Michael B Wilson

A method of enhancing carbonate precipitation in a downhole environment comprises introducing into the downhole environment a treatment composition comprising: a carbonate producing agent comprising a microbe, an enzyme, or a combination comprising at least one of the foregoing, and a substrate comprising N-oxyurea, semicarbazide, N,N-dioxyurea, or a combination comprising at least one of the foregoing. An organic feedstock and a geobacter can also be used to treating a wellbore or a subterranean formation. Encapsulated carbonate producing agent such as encapsulated bacterial spores are used to form self-healing cemented structure in a downhole environment.

Biologically mediated precipitation of carbonates for use in oilfield applications

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

A method of treating a subterranean formation penetrated by a wellbore comprises: introducing into the subterranean formation a treatment fluid comprising a carbonate producing agent, urea, and a cation source; allowing a carbonate precipitate to form, the carbonate precipitate comprising a cation from the cation source and having a water solubility of less than about 0.1 g/100 mL at 25&#xb0; C. and atmospheric pressure; and reducing or substantially preventing the passage of formation particles from the subterranean formation into the wellbore while allowing passage of formation fluids from the subterranean formation into the wellbore.

Methods of controlling fines migration in a well

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

In some embodiments, the present invention provides a recombinant protein comprising an affinity tag configured to attach the recombinant protein to a silicate surface, fused to a hydrogen sulfide scavenging enzyme.

Compositions for mitigating hydrogen sulfide contamination using a recombinant protein with an affinity tag fused to a hydrogen sulfide scavenging enzyme

Recovery of fluids from a subterranean formation during a well treatment operation is enhanced by injecting into the formation a treatment fluid comprising a sophorolipid.

Method of using Sophorolipids in well treatment operations

A method of preventing or mitigating the formation of metal sulfide scale in a fluid is provided. The fluid can be treated with an additive comprising thiamine. The fluid can be a production fluid from an oil and gas well. The production fluid can include crude oil. The fluid can include an aqueous fluid. The aqueous fluid can further include crude oil. The metal sulfide scale can include iron sulfide scale and/or zinc sulfide scale.

Method of preventing or mitigating formation of metal sulfide scales during oil and gas production

Microbial growth of at least one microorganism may be decreased, prevented, and/or inhibited in a fluid by providing ultrasonic waves to the fluid. In an optional non-limiting embodiment, an amount of at least one gas may be provided to the fluid for further decreasing the microbial population, preventing microbial growth, and/or inhibiting microbial growth. In another non-limiting embodiment, the fluid may be a downhole fluid, such as but not limited to, drilling fluids, completion fluids, production fluids, injection fluids, stimulation fluids, refinery fluids, servicing fluids, and combinations thereof. Alternatively, the fluid or downhole fluid may have a temperature ranging from about 25 C to about 100 C.

Decreasing microorganisms in fluids using ultrasonic wave technologies

Method of using sophorolipids in well treatment operations

A method of cementing a wellbore penetrating a subterranean formation comprises injecting into the wellbore a settable slurry comprising: an aqueous carrier; an aggregate; urea; a calcium source; and a calcium carbonate producing agent comprising a microbe, an enzyme, or a combination comprising at least one of the foregoing; and allowing the slurry to set.

Compositions and methods for cementing a wellbore using microbes or enzymes

Antifreeze proteins having an ice-binding site, such as those derived from thebacterium, may be used in additive compositions, fluid compositions, and methods for depressing the freezing point of the fluid compositions. The fluid composition may include the antifreeze protein and a base fluid, such as drilling fluids, servicing fluids, production fluids, completion fluids, injection fluids, refinery fluids, and combinations thereof.

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Tomball, TX, United States of America

Charles David Armstrong