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: 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: 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: 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.

Abstract: The present invention relates to compositions and methods for reducing or preventing the loss of drilling fluids and other well servicing fluids into a subterranean formation during drilling or construction of boreholes in said formation. Specifically, this invention comprises a curable cross-linkable composition capable of free radical polymerization for creating lost circulation material. The curable cross-linkable composition comprises a mixture of: (i) an organic compound capable of free radical (co)polymerization (Fp1LxQ1 and (ii) a reactive diluent (Fp2LyQ2.

Abstract: Systems and methods that utilize bremsstrahlung radiation may be used to facilitate the setting of a settable composition. For example, a method may include providing a settable composition in a portion of a wellbore penetrating a subterranean formation, a portion of the subterranean formation, or both; conveying an electron accelerator tool along the wellbore proximal to the settable composition; producing an electron beam in the electron accelerator tool with a trajectory that impinges a converter material, thereby converting the electron beam to bremsstrahlung photons; and irradiating the settable composition with the bremsstrahlung photons.

Abstract: A method of cementing a well is disclosed. The method comprising pumping into the well a cement slurry comprising a solid blend including cement, water, and a fluid loss control agent, and allowing the cement slurry to set. The fluid loss control agent comprises a styrene-butadiene latex and a high molecular-weight water-soluble polymer such as a copolymer AMPS-Am. The addition of the water-soluble polymer allows drastic reduction of the quantity of latex required to achieve fluid loss control performance and even gas migration control.

Abstract: A wellbore fluid comprises an aqueous carrier liquid, hydrophobic fibers suspended therein, hydrophobic particulate material also suspended in the carrier liquid, and a gas to wet the surfaces of the particles and fibers and bind them together as agglomerates. The wellbore fluid may be a slickwater fracturing fluid and may be used for fracturing a tight gas reservoir. Using a combination of hydrophobic particulate material, hydrophobic fibers and gas inhibits settling out of the particulate material from an aqueous liquid. Because the gas acts to wet the surfaces of both materials and agglomerates them, the particulate material is made to adhere to the fibers; the fibers form a network which hinders settling of the particulate material adhering to them, and the agglomerates contain gas and so have a bulk density which is less than the specific gravity of the solids contained in the agglomerates.

Abstract: Hydraulic cements, such as Portland cements and other cements that include substantial quantities of tricalcium silicate (C3S), dicalcium silicate (C2S), tricalcium aluminate (C3A), and/or tetracalcalcium alumino-ferrite (C4AF), are particle size optimized to have increased reactivity compared to cements of similar chemistry and/or decreased water demand compared to cements of similar fineness. Increasing hydraulic cement reactivity increases early strength development and release of reactive calcium hydroxide, both of which enhance SCM replacement and 1-28 day strengths compared to blends of conventional Portland cement and one or more SCMs, such as coal ash, slag or natural pozzolan. Decreasing the water demand can improve strength by decreasing the water-to-cement ratio for a given workability. The narrow PSD cements are well suited for making blended cements, including binary, ternary and quaternary blends.

Abstract: Methods and compositions are provided that relate to weighted elastomers. The weighted elastomers may comprise an elastomer and a weighting agent attached to an outer surface of the elastomer. An embodiment includes a weighted elastomer comprising an elastomer, and a weighting agent attached to an outer surface of the elastomer. The weighted elastomer may have a specific gravity of at least about 1.1.

Abstract: A cellulose ether having (i) one or more substituents selected from the group consisting of methyl, hydroxyethyl and hydroxypropyl, (ii) one or more hydrophobic substituents, and (iii) one or more cationic, tertiary amino, or anionic substituents, and having a retained dynamic viscosity, %?80/25, of at least 30 percent, wherein %?80/25=[dynamic solution viscosity at 80° C./dynamic solution viscosity at 25° C.]×100, the dynamic solution viscosity at 25° C. and 80° being measured as 1% aqueous solution, is useful for modifying the viscosity of a composition selected from the group consisting of wellbore servicing fluids, cementitious formulations, ceramics, metal working fluids and cutting fluids.

Abstract: Methods and compositions are provided that relate to weighted elastomers. The weighted elastomers may comprise an elastomer and a weighting agent attached to an outer surface of the elastomer. An embodiment includes a method comprising providing a fluid that comprises a weighted elastomer, wherein the weighted elastomer comprises an elastomer and a weighting agent attached to an outer surface of the elastomer; and introducing the fluid into a subterranean formation.

Abstract: The present invention provides a filtration control agent and a drilling fluid containing the same. The filtration control agent comprises the product obtained from the reaction of water, lignite, aldehyde and sulfonate polymer at 180-220° C. and the units containing sulfonate groups in the molecular chains of sulfonate polymer are at least 30 wt %. The filtration control agent provided by the present invention features a good filtration loss reduction effect and a low viscosity effect and can improve the rheological behavior of the drilling fluid, thereby meeting the requirements of the drilling of deep wells, ultra-deep wells and ultra high pressure formations.

Abstract: A self-adaptive cement formulation includes cement, water, block copolymer and asphaltite-mineral particles. The set cement demonstrates self-healing properties when exposed to methane, and is particularly suited for well-cementing applications. After placement and curing, the self-healing properties help maintain zonal isolation should bonding be disrupted between the set cement and the formation or a casing string, should cracks or defects appear in the set-cement matrix, or both.

Abstract: The present invention includes well treatment fluids and methods utilizing nano-particles and, in certain embodiments, to sealant compositions and methods utilizing nano-particles. The nano-particles may be incorporated into the sealant composition in different forms, including as discrete nano-particles, encapsulated nano-particles, agglomerated nano-particles, or in a liquid suspension.

Abstract: The invention relates to the use of a mixture comprising a mineral binder (a) and at least one SuperAbsorbent Polymer (SAP) (b), in order to improve the thermal insulation characteristics of a hardened product intended for the construction industry, by reducing its thermal conductivity ? (W·m?1·K?1), this hardened product being obtained from a dry composition or a wet formulation comprising this mixture. The dry composition, the wet formulation obtained by mixing this dry composition with water, the methods for preparing this dry composition and the corresponding wet formulation, the hardened construction products obtained from the wet formulation and the structures produced with these products, are other subjects of the invention.

Abstract: In an embodiment, the cement compositions comprise: (i) hydraulic cement, wherein the hydraulic cement has a ratio of CaO to SiO2 in the range of 2.0 to 4.0; and (ii) a water-soluble metaphosphate in a concentration of at least 2.5% bwoc. In another embodiment, the cement compositions comprise: (i) hydraulic cement, wherein the hydraulic cement has a ratio of CaO to SiO2 of less than 2.0; and (ii) a water-soluble metaphosphate; wherein any alkali nitrate is in a concentration of less than 2% bwoc; and wherein any alkali hydroxide, alkali carbonate, or alkali citrate is in a concentration of less than 0.2% bwoc. Methods of cementing in a well comprising forming either of such cement compositions and introducing it into the well are provided.

Abstract: A lightweight composite having an activated surface contains a lightweight hollow core particle having cement grains which may be adhered to the hollow core or embedded in the surface of the hollow core. The hollow core particle may be prepared from calcium carbonate and a mixture of clay, such as bentonite, and a glassy inorganic material, such as glass spheres, glass beads, glass bubbles, borosilicate glass and fiberglass.

Abstract: A variety of methods and compositions are disclosed, including, in one embodiment, a method of treating a well comprising: providing a treatment fluid comprising a base fluid and a blended cementitious component, wherein the blended cementitious component comprises kiln dust from two or more different sources; and introducing the treatment fluid into a well bore.

Abstract: A method of cementing in a subterranean formation may comprise: introducing a cement composition comprising cement, water, and a lignite-based copolymer into a subterranean formation, wherein the lignite-based copolymer comprises a lignite backbone, a first grafted monomer selected from the group consisting of -acrylamido-2-methylpropanesulfonic acid, a salt of 2-acrylamido-2-methylpropanesulfonic acid, and a second grafted monomer comprising N,N-dimethylacrylamide; and allowing the cement composition to set in the subterranean formation, wherein cement composition has a transition time of less than or equal to about 150 minutes.

Abstract: A well cementing composition comprises water, an inorganic cement, a gas generating agent and a gas stabilizer. The gas generating agent may contain materials that release hydrogen gas, carbon dioxide gas or nitrogen gas or combinations thereof. The gas stabilizer comprises an aqueous mixture comprising polyglycols, oxyalkylates and methanol, or coco trimethyl ammonium chloride, or a mixture comprising ammonium fatty alcohol ether sulfate and ethylene glycol monobutyl ether, or combinations thereof. When used to cement a subterranean well, the compositions improve the compressive strength, increase the rate at which compressive strength develops, preserve cement homogeneity, or enhance cement expansion or a combination thereof.

Abstract: A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a water-soluble crosslinkable composition, a particulate water-swellable superabsorber, and an aqueous base fluid, placing the fluid in a treated portion of the formation, wherein the treated portion comprises a first region having a first region permeability and a second region having a second region permeability, wherein a permeability contrast is a ratio between first region permeability and second region permeability, and wherein the permeability contrast is equal to or greater than 10 prior to placement of the fluid, allowing the superabsorber to occupy at least a portion of the first region, thereby reducing the first region permeability, and allowing the crosslinkable composition to penetrate at least a portion of the second region, thereby reducing the second region permeability, wherein the permeability contrast is reduced to less than 10 after placement of the fluid.

Abstract: A method of treating a treatment zone in a well is provided. The method includes the step of introducing into the treatment zone: (a) a hydrated sheet silicate mineral; and (b) a chemical activator for expanding the hydrated sheet silicate mineral. According to an embodiment, a method of treating a treatment zone in a well, where the method includes the steps of, in any order: (a) introducing into the treatment zone a first treatment fluid, wherein the first treatment fluid includes: (i) a hydrated sheet silicate mineral; and (ii) water; and (b) introducing into the zone a second treatment fluid including a chemical activator for expanding the hydrated sheet silicate mineral in the treatment zone.

Abstract: A cement slurry composition is described as having cement, water, and organic polymer particles. The composition also includes non-ionic surfactants, which may contain ethoxylate groups or contain both ethoxylate groups and propoxylate groups in the hydrophilic part. The non-ionic surfactant acts to disperse the hydrophobic polymeric particles in the slurry, thereby reducing mixing time. The cement slurry composition is prepared and then pumped into the subterranean well and placed in a zone of the subterranean well. Time is then allowed for the cement slurry composition to set and form a solid mass in the zone.

Abstract: Composition and methods using the compositions are disclosed, where the compositions include heterocyclic aromatic amines, substituted heterocyclic aromatic amines, poly vinyl heterocyclic aromatic amines, co-polymers of vinyl heterocyclic aromatic amine and non amine polymerizable monomers (ethylenically unsaturated mononers and diene monomers), or mixtures or combinations thereof in the absence of phosphate esters, optionally ethoxylated alcohols, and optionally, which form alter self-aggregating properties and/or aggregation propensities of the particles, surfaces, and/or materials.

Abstract: Methods and compositions that protect cement compositions from corrosion, particularly from wet carbon dioxide, are provided. A soluble salt additive is provided to react with reaction products generated during the reactions that occur when cement is exposed to wet carbon dioxide. The soluble salt reacts to form an insoluble salt that forms a protective layer on the surface of the cement that protects it from further corrosion from exposure to wet carbon dioxide.

Abstract: What is proposed is the use of a terpolymer comprising 5-95 mol % of 2-acrylamido-2-methylpropanesulfonic acid, 5-95 mol % of N,N-dimethylacrylamide and 5-12 mol % of acrylic acid as a fluid loss additive in well cementing.

Abstract: A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising a sealant material, helical fibers and a base fluid, placing the wellbore servicing fluid in the wellbore and/or subterranean formation, and allowing the wellbore servicing fluid to set therein.