Abstract: Methods herein may include injecting a cement slurry having an aqueous base fluid, a cement, and a plurality of cellulose nanofibers dispersed in the aqueous base fluid. The plurality of cellulose nanofibers may be present in the slurry in an amount effective to provide a slurry density of not higher than 15 lb/gal.

Abstract: An insulating fluid system includes an acidic nanosilica dispersion and an alkaline activator. The acidic nanosilica dispersion includes silica nanoparticles and a stabilizer, such as a carboxylic acid. The alkaline activator includes an alkanolamine, such as a monoalkanolamine. A mixture of the acidic nanosilica dispersion and the alkaline activator forms an insulating fluid having a pH greater than 7 and less than or equal to 12, and the insulating fluid forms an insulating gel when heated to a temperature in a range between 100° F. and 300° F. The insulating gel may be formed in an annulus between an inner conduit and an outer conduit. The inner and outer conduits may be positioned in a subterranean formation. Forming an insulating gel may include combining the acidic nanosilica dispersion with the alkaline activator to yield the insulating fluid, and heating the insulating fluid to form the insulating gel.

Abstract: Expansive cements for use in cementing subterranean wells comprise water, an inorganic cement and one or more particulate materials that swell upon contact with a water-immiscible fluid. The cements may further comprise a water-immiscible fluid. Such cements are designed to seal microannuli arising from the presence of water-immiscible fluids on casing surfaces, borehole wall surfaces or both.

Abstract: Cured cements, cement slurries, and methods of making cured cement and methods of using cement slurries are provided. The cured cement comprises cement, carbon nanotube sponges disposed within the cement, and conductive fibers disposed within the cement, in which the conductive fibers interconnect the carbon nanotube sponges and form a conductive web within the cured cement.

Abstract: A method of cementing a wellbore includes injecting into the wellbore a non-aqueous fluid; injecting into the wellbore a cement slurry and a non-ionic surfactant composition after injecting the non-aqueous fluid; and allowing the cement slurry to set, wherein the non-ionic surfactant composition comprises an alkyl end-capped ethoxylated fatty alcohol, a chain extended non-ionic surfactant, or a combination comprising at least one of the foregoing.

Abstract: Wellbore synthesis techniques are disclosed suitable for use in geothermal applications. Embodiments are provided where open hole drilled wellbores are sealed while drilling to form an impervious layer at the wellbore/formation interface. The techniques may be chemical, thermal, mechanical, biological and are fully intended to irreversibly damage the formation in terms of the permeability thereof. With the permeability negated, the wellbore may be used to create a closed loop surface to surface geothermal well operable in the absence of well casing for maximizing thermal transfer to a circulating working fluid. Formulations for the working and drilling fluids are disclosed.

Abstract: Methods and compositions for using geopolymers to create storable cementitious slurries used for oil and gas well cementing are provided. The methods of the present disclosure include providing a set-delayed geopolymer cement composition including a geopolymer; activating the set-delayed geopolymer cement composition; introducing the set-delayed geopolymer cement composition into at least a portion of a subterranean formation; and allowing the set-delayed geopolymer cement composition to set in the subterranean formation.

Abstract: Sealing composition for plugging and abandoning a wellbore and methods of plugging and abandoning a wellbore are disclosed. Embodiments of a method for plugging and abandoning a wellbore may include introducing a sealing composition into a wellbore and curing the sealing composition to form a plug. The sealing composition may include from 1 weight percent to 20 weight percent of a curing agent, based on the total weight of the composition, and from 20 weight percent to 97 weight percent of an epoxy resin system, based on the total weight of the composition. The epoxy resin system may include an epoxy resin having the formula (OC2H3)—CH2—O—R1—O—CH2—(C2H3O), where R1 is a linear or branched hydrocarbyl having from 4 to 24 carbon atoms; and a reactive diluent having the formula R—O—CH2—(C2H3O), where R is a hydrocarbyl having from 12 to 14 carbon atoms.

Abstract: Expansive cements for use in cementing subterranean wells comprise water, an inorganic cement and one or more particulate materials that swell upon contact with a water immiscible fluid. The cements may further comprise a water immiscible fluid. Such cements are designed to seal microannuli arising from the presence of water immiscible fluids on casing surfaces, borehole wall surfaces or both.

Abstract: In accordance with one or more embodiments of the present disclosure, a drilling fluid may include a base fluid and one or more formaldehyde-based resins. The drilling fluid may further comprise one or more water-insoluble acid catalyst precursors or the reaction products of such water-insoluble acid catalyst precursors. The present disclosure also describes sealed subterranean petroleum formations that include such drilling fluids and methods for sealing subterranean wellbores by utilizing such drilling fluids.

Abstract: A method to control a heat transfer profile in a defined space, the method comprising the steps of introducing a thermally insulating packer fluid into the defined space such that the thermally insulating packer fluid forms a gelled solid and reduces a rate of heat transfer through the defined space as compared to a prior rate of heat transfer through the defined space before introducing the thermally insulating packer fluid, where the thermally insulating packer fluid comprises an acidic nanosilica dispersion and a polyamine.

Abstract: A lost circulation material (LCM) composition for sealing a lost circulation zone in a wellbore is disclosed that includes from 50 weight percent to 97 weight percent epoxy resin and from 2 weight percent to 30 weight percent curing agent. The epoxy resin may include at least one of 2,3-epoxypropyl o-tolyl ether, alkyl glycidyl ethers having from 12 to 14 carbon atoms, bisphenol-A-epichlorohydrin epoxy resin, or a compound having formula (OC2H3)—CH2—O—R1—O—CH2—(C2H3O), where R1 is a linear or branched hydrocarbyl having from 4 to 24 carbon atoms. A method for isolating a lost circulation zone using the LCM compositions is also disclosed and includes introducing a spacer fluid to the lost circulation zone, introducing the LCM composition to the lost circulation zone, and curing the LCM composition in the lost circulation zone to isolate the lost circulation zone.

Abstract: A composition for sealing a lost circulation zone in a wellbore is disclosed that includes from 50 weight percent to 97 weight percent epoxy resin and from 2 weight percent to 30 weight percent curing agent based on the total weight of the composition. The epoxy resin may include at least one of 2,3-epoxypropyl o-tolyl ether, alkyl glycidyl ethers having from 12 to 14 carbon atoms, bisphenol-A-epichlorohydrin epoxy resin modified with an oxirane mono [(C12-C14)-alkyloxy)methyl] derivative, or a compound having formula (OC2H3)—CH2—O—C6H12—O—CH2—(C2H3O).

Abstract: Methods and compositions for the use of thermally responsive lost circulation materials in subterranean formations are provided. In one embodiment, the methods include introducing a treatment fluid including a base fluid and a thermally responsive lost circulation material including a thermally responsive hydrogel that includes at least one thermoresponsive polymer into a wellbore penetrating at least a portion of a subterranean formation including a loss zone; allowing the thermally responsive lost circulation material to reach a thickening transition temperature; and allowing the treatment fluid to at least partially set in the subterranean formation.

Abstract: A method of servicing a wellbore in a subterranean formation having one or more lost circulation zones comprising placing a wellbore servicing fluid comprising a sealing composition into the wellbore, wherein the sealing composition comprises a latex and an accelerator and wherein the latex, the accelerator or both are encapsulated with an encapsulation material. A wellbore servicing fluid comprising a latex and an accelerator wherein the latex, the accelerator, or both are encapsulated.

Abstract: A method of treating a subterranean formation includes introducing a well cementing composition into a wellbore, said cementing composition comprising: a pumpable slurry of cement and at least one of hydrophobic material, a superhydrophobic material, and combinations; and allowing at least a portion of the cementing composition to cure. A composition includes a pumpable slurry of wellbore cement and at least one of hydrophobic material, a superhydrophobic material, and combinations thereof.

Abstract: A shaped charge comprises a case including a wall that defines a hollow interior within the case. The wall includes an external surface and an internal surface. An explosive load is disposed within the hollow interior and positioned adjacent at least a portion of the internal surface. An initiation point chamber extends at least partially between the external surface and the internal surface of the wall. At least one self-contained, compressed explosive initiation pellet is contained within or adjacent the initiation point chamber. An exposed perforating gun carrier utilizing the shaped charge, and a method of using and producing the same are also contemplated.

Abstract: The disclosure relates to a method of delaying viscosification of a well treatment fluid within a well or within a subterranean formation penetrated by a well by introducing into the well a hydratable viscosifying agent of particulates having a minimum of 40% retention on a 60 mesh screen and a minimum of 1% retention on a 20 mesh screen.

Abstract: A composition of a cement additive material to improve durability of cementitious structures, was disclosed. The cement additive composition includes an admixture of one or more of divalent magnesium metal silicates with capacity to act as a latent hydraulic binder in said composition activated by a hydration process under aqueous conditions, and in particular the divalent metal silicate is magnesium-dominated silicate, preferably comprising mineral groups of olivines, orthopyroxenes, amphiboles, talc and serpentines or mixtures thereof. The composition also includes chloride ions or brine. Applications of the compositions are also disclosed, in particular to utilize a property of hydration as a major trigger for the latent hydraulic reaction of magnesium silicates, particularly for said olivines, when exposed to water and brines, in order to obtain a cementitious material becoming self healing.

Abstract: A variety of systems, methods and compositions are disclosed, including, in one method, providing a foamed cement composition comprising a hydraulic cement, water, a foaming surfactant, a gas, and a nanocellulose foam stabilizing additive; placing the foamed cement composition in a selected location; and allowing the foamed cement composition to set.

Abstract: Provided here are a wellbore servicing composition, methods of making same, and methods of servicing a wellbore penetrating a subterranean formation using same. The wellbore servicing composition comprises cement kiln dust (CKD), an organic acid, and water. A method of servicing a wellbore penetrating a subterranean formation comprises placing the wellbore servicing composition into the wellbore. The wellbore servicing composition can be used as a spacer fluid in a wellbore servicing operation.

Abstract: Systems and methods for modifying rheology of a cement slurry are described. Systems and methods may include a composition including at least one of: one or more polycarboxylate ethers (PCEs); one or more functionalized polyacrylamide co-polymers; and one or more polysaccharide biopolymers (BP).

Abstract: An example wellbore cementing system includes a casing to line at least part of a wellbore, and a pipe to introduce cement slurry containing capsules into the wellbore. The capsules include an accelerator. The accelerator reacts with the cement slurry to affect a thickening time of the cement slurry. The example system also includes a substructure having shearing pins. The substructure is arranged to receive the cement slurry from the pipe. The substructure is configured rotate to break at least some of the capsules in the cement slurry.

Abstract: A method for measuring one or more properties of a formation includes applying a magnetic field to a subterranean formation using a downhole tool. A radiofrequency signal is transmitted into the subterranean formation that is exposed to the magnetic field. The radiofrequency signal induces a transverse magnetization in the subterranean formation, and the transverse magnetization induces an initial voltage signal in the downhole tool. The initial voltage signal is amplified using a first amplifier in the downhole tool such that the first amplifier outputs a first amplified voltage signal. The first amplified voltage signal is introduced to an input of the first amplifier, such that the first amplifier amplifies the first amplified voltage signal and outputs a second amplified voltage signal.

Abstract: A method of treating a subterranean formation includes introducing a well cementing composition into a wellbore, the cementing composition comprising: a pumpable slurry of cement and at least one of hydrophobic material, a superhydrophobic material, and combinations; and allowing at least a portion of the cementing composition to cure. A composition includes a pumpable slurry of wellbore cement and at least one of hydrophobic material, a superhydrophobic material, and combinations thereof.

Abstract: Engineering bead slurries may be useful in producing lightweight cement slurries for use in subterranean cementing operations. For example, a method may include engineering a bead slurry to have a shelf-life of about 1 month or greater by performing at least one of (1) calculating the shelf-life for the bead slurry and (2) calculating a minimum yield point required to prevent a lightweight bead of the bead slurry from floating or settling in the bead slurry; wherein the bead slurry comprises a gelled base fluid and a plurality of lightweight beads having a specific gravity of about 0.8 or less; producing the bead slurry; mixing the bead slurry and a cement slurry to yield a lightweight cement slurry; introducing the lightweight cement slurry into a wellbore penetrating a subterranean formation; and allowing the lightweight cement slurry to set therein.

Abstract: A variety of systems, methods and compositions are disclosed. A method of well treatment may comprise providing a well treatment fluid comprising a base fluid and a delayed hydratable polymer, wherein the delayed hydratable polymer comprises a hydratable polymer and amorphous silica. The method may further comprise introducing the well treatment fluid into a wellbore.

Abstract: Provided by the present invention is an additive for a slurry being capable of inhibiting viscosity elevation and dehydration at high temperatures at low cost, through use for a slurry for civil engineering and construction (for example, a drilling mud and a drilling cement slurry for use in well drilling. etc.), and the like. A powdery additive for a slurry, the powdery additive containing a vinyl alcohol polymer, which has: a solubility of 25% or less when immersed in hot water at 60° C. for 3 hours; a degree of saponification of at least 99.5 mol %; an average degree of polymerization of at least 1,500 and 4,500 or less; and the amount of 1,2-glycol linkage of 1.8 mol % or less, the powdery additive being capable of passing through a sieve having a nominal mesh opening size of 1.00 mm.

Abstract: Application of biodegradable oils to additive particles to control dusting. A method of reducing an amount of dust produced during transfer of additive particles comprising: treating at least some of the additive particles with one or more biodegradable oils; storing the additive particles; and transferring the additive particles prior to and after storage, wherein biodegradable oil reduces the amount of dust produced during at least one of the transfers of the additive particles.

Abstract: Compositions, systems, and methods for delivering treatment chemicals, for example, to enhance conductivity in microfractures and/or low-permeability formations, are provided. In one embodiment, the methods comprise: providing a treatment fluid that comprises a base fluid and a plurality of microbubbles, wherein one or more of the microbubbles each comprise at least an outer shell and a treatment chemical within the shell, and have a diameter of about 100 microns or less; and introducing the treatment fluid into at least a portion of a subterranean formation. In some embodiments, the microbubbles may enter one or more microfractures in the subterranean formation and release the treatment chemical therein.

Abstract: A composition forming a free-flowing cement additive, the composition comprising a high viscosity elastomer, the high viscosity elastomer having a viscosity between 50,000 cP and 300,000 cP at room temperature; and an inert support, where the high viscosity elastomer is deposited on the inert support.

Abstract: An oil-swellable gel lost circulation material (LCM) formed from an elastomeric polymer and a crosslinker amine is provided. The LCM may include gel pieces cut from gel strands formed from an elastomeric polymer and a crosslinker amine. The oil-swellable gel LCM composition may be formed by mixing an elastomeric polymer solution with a crosslinker amine and heating the mixture to form a crosslinked gel. The gel may be extruded through a die having orifices into a non-solvent and allowed to desolvate in the presence of the non-solvent. The gel strands may be dried and cut into gel pieces to form an LCM. The resulting LCM may swell when introduced to a loss circulation zone in the presence of a non-aqueous fluid such as a drilling mud or component of a drilling mud.

Abstract: An oil-swellable gel lost circulation material (LCM) formed from an elastomeric polymer and a crosslinker amine is provided. The LCM may include gel pieces cut from gel strands formed from an elastomeric polymer and a crosslinker amine. The oil-swellable gel LCM composition may be formed by mixing an elastomeric polymer solution with a crosslinker amine and heating the mixture to form a crosslinked gel. The gel may be extruded through a die having orifices into a non-solvent and allowed to desolvate in the presence of the non-solvent. The gel strands may be dried and cut into gel pieces to form an LCM. The resulting LCM may swell when introduced to a loss circulation zone in the presence of a non-aqueous fluid such as a drilling mud or component of a drilling mud.

Abstract: A method of controlling the setting time of a geopolymer by coating aluminosilicate particles with nanoparticles to slow the geopolymerization reaction. The coating effectiveness of the nanoparticles may be enhanced by pretreating the aluminosilicate particles with a layer-by-layer assembly of polyelectrolytes. A geopolymer is formed by mixing about 39% to about 66% by weight aluminosilicate source, about 0% to about 40% by weight sand, about 19% to about 33% by weight of alkali activator solution, and about 1% to about 4% nanoparticles.

Abstract: An oil-swellable gel lost circulation material (LCM) formed from an elastomeric polymer and a crosslinker amine is provided. The LCM may include gel pieces cut from gel strands formed from an elastomeric polymer and a crosslinker amine. The oil-swellable gel LCM composition may be formed by mixing an elastomeric polymer solution with a crosslinker amine and heating the mixture to form a crosslinked gel. The gel may be extruded through a die having orifices into a non-solvent and allowed to desolvate in the presence of the non-solvent. The gel strands may be dried and cut into gel pieces to form an LCM. The resulting LCM may swell when introduced to a loss circulation zone in the presence of a non-aqueous fluid such as a drilling mud or component of a drilling mud.

Abstract: Cement compositions containing a cement component and an oil-immiscible solvent and methods for using same are provided. In another aspect, methods for sealing subterranean zones are provided that include emplacing a cement composition into a wellbore containing a cement component and an oil-immiscible solvent, contacting the cement composition with a water source, and reacting the cement composition with the water source to form a hardened cement.

Abstract: A method of minimizing vapor transmission from a constructed permeability control infrastructure can comprise forming a heterogeneous hydrated matrix within the constructed permeability control infrastructure, the constructed permeability control infrastructure comprising a permeability control impoundment defining a substantially encapsulated volume. The heterogeneous hydrated matrix includes a particulate solid phase and a continuous liquid phase which is penetrable by a vapor having a permeation rate. The constructed permeability control infrastructure is operated to control the permeation rate by manipulating an operational parameter of the constructed permeability control infrastructure. Additionally, the vapor can be impeded during operating sufficient to contain the vapor within the constructed permeability control infrastructure.

Abstract: The present invention relates to the deep-well drilling fluid field, and discloses a high-temperature crosslinking deep-well drilling fluid and a method for preparing the high-temperature crosslinking deep-well drilling fluid. The high-temperature crosslinking deep-well drilling fluid contains water, bentonite, sulfomethylated phenolic resin, sulfonated lignite, halide salt, filtrate reducer, sodium polyacrylate and barite, wherein, based on 100 parts by weight of water, the content of the bentonite is 3.5-5 parts by weight, the content of the sulfomethylated phenolic resin is 6-8 parts by weight, the content of the sulfonated lignite is 6-8 parts by weight, the content of the halide salt is 7.5-12 parts by weight, the content of the filtrate reducer is 0.5-1.2 parts by weight, the content of the sodium polyacrylate is 0.8-1.7 parts by weight, and the content of the barite is 250-300 parts by weight.

Abstract: An exemplary method includes introducing a treatment fluid comprising nano-hydraulic cement into a subterranean formation. The treatment fluid may include a drilling fluid, a completion fluid, a stimulation fluid, a well clean-up fluid or a cement composition. Another example method comprises introducing a cement composition comprising nano-hydraulic cement, hydraulic cement, and water into a subterranean formation; and allowing the cementing composition to set in the subterranean formation. An example well treatment fluid comprises nano-hydraulic cement.

Abstract: The present application relates to an oil and gas treatment composition comprising (i) a blend of hydroxyethyl cellulose (HEC) and crosslinked polyvinylpyrrolidone, (ii) an aqueous based continuous phase, (iii) a reactive clay or shale material, and (iv) at least one drilling fluid additive. The present application also relates to a method for inhibiting hydration of clays or shale materials in drilling a subterranean well using the composition. A different embodiment of the application discloses that the composition additionally comprises organophilic clay, a stabilizer and white medicinal oil.

Abstract: The present invention relates to the deep-well drilling fluid field, and discloses a deep-well polysulfonate drilling fluid and a method for preparing the deep-well polysulfonate drilling fluid. The drilling fluid contains water, bentonite, sodium carbonate, sulfomethylated phenolic resin, sulfonated lignite, halide salt, filtrate reducer, sodium polyacrylate, sodium bisulfite and barite, wherein, based on 100 parts by weight of water, the content of the bentonite is 3.5-5 parts by weight, the content of the sodium carbonate is 0.15-0.35 parts by weight, the content of the sulfomethylated phenolic resin is 6-8 parts by weight, the content of the sulfonated lignite is 6-8 parts by weight, the content of the halide salt is 7.5-12 parts by weight, the content of the filtrate reducer is 0.5-1.2 parts by weight, the content of the sodium polyacrylate is 0.8-1.

Abstract: Provided is an active light sensitive or radiation sensitive resin composition which contains a compound (A) represented by General Formula (I) or (II): in the formulae, each of Y1 and Y2 represents a monovalent organic group; each of M1+ and M2+ represents an organic onium ion; each of X1 and X2 represents a group that is represented by —S—, —NH—, or —NR1—; R1 represents a monovalent organic group; each of n1 and n2 represents an integer of 1 or more; and R1 and Y1 or Y2 may bond with each other to form a ring.

Abstract: Embodiments disclosed herein relate to aqueous based wellbore fluids for preventing wellbore fluid loss downhole containing at least one copolymer formed from at least one natural polymer monomer and at least one latex monomer, and an aqueous base fluid.

Abstract: Pumpable process-fluid compositions comprise polyacrylamide, a non-metallic crosslinker and a pH-adjustment material. Such compositions have utility in the context of controlling lost circulation in subterranean wells. Upon entering at least one lost circulation zone, the compositions crosslink, thereby forming a barrier that minimizes or stops fluid flow from the wellbore into the lost circulation zone.

Abstract: Disclosed is a method of cementing. The method comprises providing a set-delayed cement composition comprising water, pumice, hydrated lime, a set retarder, and a micro-electrical-mechanical system; and allowing the set-delayed cement composition to set.

Abstract: Methods comprising providing a sealant composition comprising an aqueous base fluid and a crosslinkable polymer composition, wherein the crosslinkable polymer composition comprises a crosslinkable organic polymer and a crosslinker; introducing an elastic gellable composition into the sealant composition, wherein the elastic gellable composition is an aqueous emulsion comprising an aqueous continuous phase and a dispersed phase comprising elastomeric polymers; introducing the sealant composition into a subterranean formation; and crosslinking the sealant composition into a gel to form a seal in the subterranean formation, thereby forming an elastic gelled sealant composition, wherein the elastic gellable composition reduces the brittleness of the elastic gelled sealant composition as compared to the sealant composition without the elastic gellable composition.

Abstract: A method is for sealing hydrocarbon wells, wherein a composition is used. The composition comprises a prepolymer; a free radical initiator; a hydraulic material; a monomer and water. The composition further comprises an inhibitor.

Abstract: A variety of methods and compositions, including, in one embodiment, a method that comprises providing a treatment fluid comprising a carrier fluid and temperature-activated polymeric particulates. The temperature-activated polymeric particulates may include a compressible gas trapped in the temperature-activated polymeric particulates. The method may further comprise introducing the treatment fluid into a well bore annulus.

Abstract: Methods including providing a wellbore in a subterranean formation; providing a proposed cement slurry; calculating a fluid migration threshold; manipulating the proposed cement slurry based on the fluid migration threshold so as to produce a fluid migration resistant cement slurry; introducing the fluid migration resistant cement slurry into the wellbore in the subterranean formation; and curing the fluid migration resistant cement slurry in the wellbore in the subterranean formation.

Abstract: A method of measuring and controlling a temperature distribution at a member is disclosed. A probe is placed proximate the member. The probe has a plurality of longitudinally-spaced reflective elements. An ultrasonic pulse is generated at a selected location of the probe so as to propagate along the probe. Reflected pulses are received at the selected location from the plurality of longitudinally-spaced reflective elements. The distribution of temperature at the member is determined from the reflected pulses. The determined distribution of temperature may be used in controlling the temperature of the member. The member may be a solid or fluid.