Compositions and methods for use in fracturing treatments using friction reducing additives that include nanoparticles are provided. In some embodiments, the methods include: providing a treatment fluid that includes an aqueous base fluid and a friction reducing additive, the friction reducing additive including at least one polymer and a plurality of nanoparticles; and introducing the treatment fluid into a portion of a subterranean formation at or above a pressure sufficient to create or enhance at least one fracture in the subterranean formation.

A modified high density brine for use in subterranean drilling and completion operations. The modified high density brine includes a heavy brine and the addition of high density particles. The resultant modified high density brine eliminates the need for toxic, corrosive, and costly ZrBr.sub.2 or cesium formate additions or other ionic additives to boost the density of the modified high density brine to more than 14 lbs./gallon.

Provided is a composition that may include an aqueous phase, and extremophilic bacteria having signal transduction chemotaxis machinery and nanoemulsion oil droplets including metal-silica nanoparticles attached to a surface thereof. Further provided is a method for treating an oil reservoir, that may include introducing into the oil reservoir an extremophilic bacteria having signal transduction chemotaxis machinery and nanoemulsion oil droplets including metal-silica nanoparticles attached to a surface thereof. Further provided is method for bacteria mediated enhanced oil recovery that may include introducing extremophilic bacteria downhole to an oil reservoir. The method may further include triggering cell lysis of the extremophilic bacteria, mobilizing the oil trapped by the biosurfactants released from lysed extremophilic bacteria, and producing the oil trapped by the biosurfactants from the oil reservoir.

Method of making and using a proppant from captured carbon in either a carbon mineralization process or in a carbon nanomaterial manufacturing process, followed by treatments to ensure the quality control of the proppants so that they are suitable for use in hydraulic and other reservoir fracturing methods.

Well treatment operation comprises introducing nanosized particulates into a formation. The nanosized particulates are synthesized by combining PMIDA, a calcium source, a pH adjusting agent, and an aqueous medium. This combination results in a degradable (i.e., dissolvable) solid that can be used in heterogeneous formations like shale type rock reservoirs, as well as sedimentary rock formations like clastic, siliclastic, sandstone, limestone, calcite, dolomite, and chalk formations, and formations where there is large fluid leak-off due to stimulation treatments. The disclosed particulates may also be used for acidizing treatments in mature fields and deep water formations commonly characterized by high permeability matrices. The solubility of the particulates advantageously allows the material to act as a temporary agent having a lifespan that is a function of temperature, water flux, and pH, making it adaptable to various reservoir conditions with minimal to no risk of adverse effects on the reservoir.

A non-linear surfactant, and particularly a non-linear surfactant comprising bi-functionalized molecules or particles having both hydrophobic and hydrophilic groups. The non-linear surfactant includes a nanoparticle template of a rigid molecular structure, wherein the nanoparticle comprises a molecule or a particle that is bi-functionalized with both hydrophilic and hydrophobic groups to obtain an amphiphilic nanoparticle. The template nanoparticle can be used as a surfactant, wetting agent, emulsifier, detergent or other surface active agents or for the preparation of nanoemulsions or dispersions. The non-linear surfactant can provide smaller particle sizes for emulsion suspensions and foams.

A method for zonal isolation in a subterranean formation includes identifying a zone of interest within the subterranean formation, determining a static temperature of the zone of interest, determining a time duration for gelation of a treatment fluid, determining a concentration of an accelerator in the treatment fluid, determining a volume of the treatment fluid to be delivered to the zone of interest, determining a correlation between cooling of a wellbore near the zone of interest and a delivery rate of the treatment fluid, determining a target wellbore temperature, delivering a cooling stage until the target wellbore temperature is reached, and delivering a treatment stage. Delivering the cooling stage and the treatment stage results in forming, within the zone of interest, a gel that is impermeable to fluid flow.

The invention relates to a nanofluid preparation method (100) from biogenic material, said method comprising the steps of: Treating (120) biogenic material with a strong acid to remove metal impurities; Heating (140) the treated biogenic material at a first temperature comprised between 150° C. and 500° C.; Heating (150) the treated biogenic material at a second temperature above 600° C. to pyrolyze the treated biogenic material; Grinding (160) the pyrolyzed biogenic material to obtain nanoparticles of biogenic material; and Mixing (180) nanoparticles of biogenic material with an organic solvent to form a nanofluid, said organic solvent comprising a low polarity solvent. The invention also relates to a nanofluid obtainable by the nanofluid preparation method and the use of such a nanofluid for example for reducing fines migration or enhanced crude oil recovery. The invention also relates to a system for enhanced crude oil recovery from a reservoir well.

The present disclosure relates to the gas production industry. A shielding formation member, for which use is made of an emulsion-suspension system with colloidal nano-particles of silicon dioxide is injected into the bottom region of a formation, the system comprising (% by vol.): 5-12 of diesel fuel or processed oil from an oil processing and pumping station, 2-3 of emulsifier, and 1.0-1.5 of colloidal nano-particles of silicon dioxide, with the remainder being an aqueous solution of calcium chloride or potassium chloride. The emulsifier used is a composition comprising (% by vol.): 40-42 of esters of higher unsaturated fatty acids and resin acids, 0.7-1 of amine-N-oxide, 0.5-1 of high-molecular-weight organic heat stabilizer, with the remainder being diesel FUEL.

Provided is a composition that may include an aqueous phase, and extremophilic bacteria having signal transduction chemotaxis machinery and nanoemulsion oil droplets including metal-silica nanoparticles attached to a surface thereof. Further provided is a method for treating an oil reservoir, that may include introducing into the oil reservoir an extremophilic bacteria having signal transduction chemotaxis machinery and nanoemulsion oil droplets including metal-silica nanoparticles attached to a surface thereof. Further provided is method for bacteria mediated enhanced oil recovery that may include introducing extremophilic bacteria downhole to an oil reservoir. The method may further include triggering cell lysis of the extremophilic bacteria, mobilizing the oil trapped by the biosurfactants released from lysed extremophilic bacteria, and producing the oil trapped by the biosurfactants from the oil reservoir.