Abstract: An apparatus for flowing and mixing cement within a subterranean formation includes a housing, a flow control device, and baffles. The housing is configured to contain a cement additive. The housing includes a first end and a second end. The first end is configured to couple to a cement retainer. The flow control device is disposed at the second end of the housing. The baffles are disposed within the housing.

Abstract: A drilling fluid composition includes a latex including a first polymer and a second polymer. The first polymer includes polyvinyl alcohol and polyvinyl acetate. A molar concentration of the polyvinyl alcohol in the first polymer is greater than 80% and less than 100%. The second polymer has a general structure in which x is an overall molar ratio of styrene in the second polymer, y is an overall molar ratio of butadiene in the second polymer, and z is an overall molar ratio of carboxylic acid in the second polymer. A sum of x, y, and z is represented as s. Styrene (x) is in a range of from about 20% to about 30% of s. Butadiene (y) is in a range of from about 70% to about 80% of s. Carboxylic acid (z) is in a range of from about 1% to about 5% of s.

Abstract: A method to incorporate calcined Saudi calcium bentonite as a low-density cement admixture in oil and gas well applications. Low-density cement systems were designed using the calcined Saudi calcium bentonite in an amount of from 10 to 30 weight % of the admixture to form a low-density cement slurry at a density of from 10 pounds per gallon (ppg) to 15 ppg; and injecting the low-density cement slurry into the well to seal the well from the geological formation; and curing the low-density cement slurry in the well to seal the well from the geological formation.

Abstract: A method for manipulating hydraulic fracture geometry. In one embodiment, the method comprises injecting a fracturing fluid into a well to generate one or more hydraulic fractures in a subsurface rock formation and then substantially draining any fluids from the one or more hydraulic fractures. The method may further comprise injecting a hydrophilic polymer and one or more crosslinking agents into the well to subsequently form low-density hydrogels which may then screen out only each tip of the one or more hydraulic fractures. A working fluid may then be injected into the well to increase fracture width of the one or more hydraulic fractures without substantially increasing fracture length. In an alternative embodiment, the hydrophilic polymer may be fully crosslinked by the one or more crosslinking agents and injected as pre-formed particle gels (PPGs) which may also screen out only each tip of the one or more hydraulic fractures.

Abstract: Disclosed herein is a composition comprising a cementitious material, a pozzolanic material, aplite, and an aqueous fluid. Also disclosed herein is a method of servicing a wellbore penetrating a subterranean formation, comprising: placing the composition into the wellbore; and allowing the composition to form a set cement. The composition can develop suitable mechanical properties and permeability after setting in a wellbore and be expansive.

Abstract: Cementing compositions containing a hydraulic cement, halloysite nanoparticles, and silica flour. The cementing compositions may optionally include other additives such as a friction reducer, a defoamer, and a fluid loss additive. Cement samples made therefrom and methods of producing such cement samples are also specified. The addition of halloysite nanoparticles and silica flour provides enhanced mechanical strength (e.g. compressive strength, flexural strength) and improved durability (e.g. resistance to CO2 and salinity) to the cement, making them suitable cementing material for oil and gas wells.

Abstract: In wellbore abandonment operations using recycled tire rubber, a quantity of shredded rubber obtained by shredding waste tires is mixed with a quantity of a wellbore fluid to form a wellbore abandonment fluid. A first plug of cement is flowed into a wellbore to be abandoned. After the first plug of cement has set, the wellbore abandonment fluid is flowed into the wellbore such that the wellbore abandonment fluid contacts and is uphole of the first plug of cement within the wellbore. After flowing the wellbore abandonment fluid into the wellbore, a second plug of cement is flowed into the wellbore such that the second plug of cement contacts and is uphole of the wellbore abandonment fluid.

Abstract: A method of cementing a wellbore comprises combining a liquid additive with a cement slurry, the liquid additive comprising a metal gluconate, an alkali metal or an alkaline earth metal salt, an alkanolamine, a dispersant, and water to form a cementing composition; injecting the cementing composition into the wellbore; and allowing the cementing composition to set.

Abstract: A drilling fluid and method for drilling in a coal containing formation. The method includes: providing a mixed metal-viscosified drilling fluid including at least 1% potassium salt; circulating the drilling fluid through the well; and drilling into a coal seam.

Abstract: The present disclosure to a cementitious plugging wall solidifier for water-based drilling fluid and a preparation method thereof and a water-based drilling fluid.

Abstract: Well material distribution methods may include gravity feeding bulk well materials including at least one well material component into a mixing vessel which may include a mixing vessel interior and at least one mixing device disposed in the mixing vessel interior; forming a well material mixture by mixing the bulk well materials including at least one well material component in the mixing vessel interior of the mixing vessel via operation of the at least one mixing device; distributing the well material mixture from the mixing vessel interior of the mixing vessel to at least one mud pit; and distributing a substantially homogenous well material mixture from the at least one mud pit to a hydrocarbon well.

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: Disclosed herein are degradable diverter materials comprising a polyacrylate compound. In particular, the degradable diverter material may be a particulate with each individual particle being having a polyacrylate compound and optionally at least one inert filler. The degradable diverter material may be introduced into a wellbore penetrating a subterranean formation. The degradable diverter material may then be allowed to divert at least a portion of fluid present downhole, the fluid being introduced from the surface or already present downhole. The degradable diverter material can then be allowed to at least partially degrade via dissolution.

Abstract: Solid shale inhibitor additives and methods of using such additives to, for example, inhibit shale are provided. In some embodiments, such methods include providing an aqueous treatment fluid that includes an aqueous base fluid and a solid shale inhibitor additive, the solid shale inhibitor additive including carrier particles and a treatment composition that includes a shale inhibitor; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.

Abstract: Methods of wellbore cementing are provided. A method of generating a wellbore treatment fluid may include: classifying a plurality of solid particulates using correlations; calculating a reactive index and/or a water requirement for at least one of the solid particulates; and selecting two or more solid particulates from the plurality of solid particulates to create a wellbore treatment fluid.

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.