Abstract: A method of treating a lost circulation zone in a wellbore includes contacting an accelerant composition comprising triethanolamine with a cement composition in the lost circulation zone, the cement composition comprising at least: from 1 weight percent (wt. %) to 90 wt. % cement precursor based on the total weight of the cement composition; and from 5 wt. % to 70 wt. % water based on the total weight of the cement composition; where a weight ratio of triethanolamine to the cement precursor is from 0.1 percent (%) to 60%; and curing the cement composition in the lost circulation zone to form a cured cement, where the triethanolamine accelerates the curing rate of the cement composition and the cured cement seals the lost circulation zone.

Abstract: Lost circulation material (LCM) compositions may include an epoxy resin, an emulsifier comprising a polyaminated fatty acid, water, a crosslinker, and an optional cementitious and/or weighting agent. These LCM compositions may have a density of from about 63 pounds per cubic foot (pcf) to about 99 pcf and may be capable of being injected through a drill bit of a drill string into a lost circulation zone in wellbores. Corresponding methods of eliminating or reducing lost circulation in a lost circulation zone from a well may include introducing these LCM compositions into the well.

Abstract: According to one or more embodiments of the present disclosure, a method for hydraulic fracturing includes pumping a hydraulic fracturing fluid through a wellbore into a subterranean formation at a pressure greater than a fracturing pressure of the subterranean formation. The hydraulic fracturing fluid may include an aqueous base fluid and a clay stabilizer consisting of one or more polyethylene polyamines having a first structure H2NCH2CH2(NHCH2CH2)xNH2, where x is an integer greater than or equal to 3. The amount of the clay stabilizer may be from 1 lbm/bbl to 20 lbm/bbl relative to the total volume of the hydraulic fracturing fluid. The average molecular weight of the polyethylene polyamines in the hydraulic fracturing fluid having the first chemical structure may be from 200 g/mol to 400 g/mol. All of the polyethylene polyamines in the hydraulic fracturing fluid having the first chemical structure may be encompassed in the clay stabilizer.

Abstract: According to one or more embodiments of the present disclosure, a cement slurry includes cement particles, an aqueous fluid in an amount of from 10 wt. % to 70 wt. % relative to the total weight of the cement particles, and a clay stabilizer consisting of one or more polyethylene polyamines having a first structure H2NCH2CH2(NHCH2CH2)xNH2, where x is an integer greater than or equal to 3. The amount of the clay stabilizer may be from 1 wt. % to 10 wt. % relative to the total weight of the cement particles. The average molecular weight of the polyethylene polyamines in the cement slurry having the first chemical structure may be from 200 g/mol to 400 g/mol. All of the polyethylene polyamines in the cement slurry having the first chemical structure may be encompassed in the clay stabilizer. Methods for cementing a casing in a wellbore using the cement slurry are also disclosed.

Abstract: A method may include obtaining, in real-time, well data regarding a wellbore and drilling fluid data regarding drilling fluid circulating in the wellbore. The method may further include determining, based on the drilling fluid data, a plastic viscosity (PV) value and a yield point (YP) value regarding the drilling fluid. The method may further include determining, based on the well data and the drilling fluid data, an equivalent circulating density (ECD) value of an annulus of the wellbore. The method may further include determining a hole cleaning efficiency (HCE) value based on a hole cleaning model, the PV value, the YP value, and the ECD value. The method may further include determining an adjusted rate of penetration (ROP) value for a drilling operation in the wellbore based on the HCE value and a current ROP value. The method may further include transmitting a command to a drilling system that produces the adjusted ROP value in the drilling operation.

Abstract: Drilling fluid compositions and methods for using drilling fluid compositions are provided with enhanced anti-bit balling properties that include an aqueous-based fluid, one or more drilling fluid additives, and an anti-bit balling additive. The anti-bit balling additive may be an epoxidized ?-olefin and the drilling fluid may include the anti-bit balling additive in an amount ranging from about 0.5 ppb to about 20 ppb. Methods for using the drilling fluid compositions may further include mixing an aqueous base fluid with one or more drilling fluid additives and an anti-bit balling additive, wherein the anti-bit balling additive includes epoxidized ?-olefin and the drilling fluid may include the anti-bit balling additive in an amount ranging from about 0.5 ppb to about 20 ppb, and introducing the drilling fluid to a subterranean formation.

Abstract: An apparatus includes a tool body having a bore that is aligned with a lengthwise axis and a rotating assembly coupled to the tool body. The rotating assembly includes a turbine wheel that is disposed adjacent to an inner surface of the wall and exposed to the bore. The rotating assembly includes an impeller that is disposed adjacent to an outer surface of the wall in a position corresponding to the turbine wheel. Each of the turbine wheel and impeller has a respective axis of rotation that is transverse to the lengthwise axis. The rotating assembly includes a link rod that couples the turbine wheel to the impeller and is used to transfer mechanical energy generated by the turbine wheel to the impeller. The apparatus is operable by fluid flow through a drill string to increase pressure in a wellbore annulus and enhance transportation of formation cuttings up the annulus.

Abstract: A lost circulation material (LCM) composition for sealing lost circulation zones in wellbores may include 50 weight percent to 97 weight percent epoxy resin, 2 weight percent to 30 weight percent curing agent, 0.1 weight percent to 40 weight percent weighting material, and 0.1 weight percent to 20 weight percent amide accelerator. The LCM composition may have a density of greater than or equal to 1121 kilograms per cubic meter and may be capable of being injected through a drill bit of a drill string into the lost circulation zone. The amide accelerator may enable the viscosity of the LCM composition to be reduced while providing a reduced cure time. The LCM compositions are suitable for treating high-injectivity lost circulation zones.

Abstract: Embodiments disclosed relate to a composition and a method of treating a formation. The method includes introducing a loss circulation material system through a wellbore into a formation, where the loss circulation material system is comprised of an esterified derivative of an epoxidized organic material and a curing agent. The esterified derivative of an epoxidized organic material has a formula of: where R? comprises H, a substituted or an unsubstituted (C1-C12) hydrocarbyl group; and where R? comprises a substituted or an unsubstituted (C2-C30) hydrocarbyl group, including where at least one oxygen atom is attached to two different adjacent carbon atoms of the (C2-C30) hydrocarbyl group. The method also includes maintaining wellbore conditions such that the loss circulation material system cures into a loss circulation material in the formation. The cured loss circulation material may withstand a pressure differential up to about 20,000 psid.

Abstract: Drilling fluid compositions and methods for using drilling fluid compositions are provided with enhanced anti-bit balling properties that includes an aqueous base fluid, one or more drilling fluid additives, and an anti-bit balling additive where the anti-bit balling additive comprises a C15-C18 alkene or a mixture of two or more C15-C18 alkenes. Methods for using the drilling fluid compositions may further include mixing the mixing an aqueous base fluid with one or more drilling fluid additives and an anti-bit balling additive, wherein the anti-bit balling additive includes a C15-C18 alkene or a mixture of two or more C15-C18 alkenes, and introducing the drilling fluid to a subterranean formation.

Abstract: A method includes introducing an epoxy resin system to a wellbore defect in a wellbore. The epoxy resin system comprises a polyhedral oligomeric silsesquioxane (POSS) epoxy resin with at least one reactive group and a curing agent. The method includes maintaining the epoxy resin system in the wellbore such that a cured epoxy resin system product forms in the wellbore defect.

Abstract: A corrosion inhibiting cement composition for reducing corrosion of wellbore casings is disclosed that includes from 10 weight percent to 70 weight percent cement precursor, from 5 weight percent to 70 weight percent water, from 0.1% to 60% by weight of cement amine corrosion inhibitor, where the amine corrosion inhibitor comprises a polyethylene polyamine. A method for reducing corrosion of wellbore casings includes dispensing the corrosion inhibiting cement compositions into the annulus and allowing the corrosion inhibiting cement composition to cure to form a hardened cement, where the corrosion inhibiting cement composition includes a cement composition and the amine corrosion inhibitor.

Abstract: A method of reducing corrosion in tubular strings installed in wellbores includes dispensing an accelerated cement composition into a wellbore annulus, a casing-casing annulus, or both, the accelerated cement composition comprising a cement composition and an accelerant composition, where: the cement composition comprises a cement precursor and water; the accelerant composition comprises triethanolamine; and a concentration of the triethanolamine in the accelerated cement composition is greater than or equal to 10,000 parts per million by weight; allowing the accelerated cement composition to cure in the annulus to form a cured cement, where the triethanolamine reacts with a metal of the tubular string, the reaction forming a protective layer on the surfaces of the tubular string that inhibits dissolution of iron from the metal of the tubular string.

Abstract: Drilling fluid compositions and methods for using drilling fluid compositions are provided with enhanced anti-bit balling properties that include an aqueous-based fluid, one or more drilling fluid additives, and an anti-bit balling additive. The anti-bit balling additive may be an epoxidized ?-olefin and the drilling fluid may include the anti-bit balling additive in an amount ranging from about 0.5 ppb to about 20 ppb. Methods for using the drilling fluid compositions may further include mixing an aqueous base fluid with one or more drilling fluid additives and an anti-bit balling additive, wherein the anti-bit balling additive includes epoxidized ?-olefin and the drilling fluid may include the anti-bit balling additive in an amount ranging from about 0.5 ppb to about 20 ppb, and introducing the drilling fluid to a subterranean formation.

Abstract: A method of treating a lost circulation zone in a wellbore includes contacting an accelerant composition comprising triethanolamine with a cement composition in the lost circulation zone, the cement composition comprising at least: from 1 weight percent (wt. %) to 90 wt. % cement precursor based on the total weight of the cement composition; and from 5 wt. % to 70 wt. % water based on the total weight of the cement composition; where a weight ratio of triethanolamine to the cement precursor is from 0.1 percent (%) to 60%; and curing the cement composition in the lost circulation zone to form a cured cement, where the triethanolamine accelerates the curing rate of the cement composition and the cured cement seals the lost circulation zone.

Abstract: Drilling fluid compositions and methods for using drilling fluid compositions are provided with enhanced lubricating properties that include an aqueous-based fluid, one or more drilling fluid additives, and a lubricating additive. The lubricating additive may be an epoxidized ?-olefin and the drilling fluid may include the lubricating additive in an amount ranging from about 1 ppb to about 20 ppb. Methods for using the drilling fluid compositions may further include mixing an aqueous base fluid with one or more drilling fluid additives and a lubricating additive, wherein the lubricating additive includes epoxidized ?-olefin and the drilling fluid may include the lubricating additive in an amount ranging from about 0.5 ppb to about 20 ppb, and introducing the drilling fluid to a subterranean formation.

Abstract: Drilling fluid compositions and methods for using drilling fluid compositions are provided with enhanced anti-bit balling properties that includes an aqueous base fluid, one or more drilling fluid additives, and an anti-bit balling additive where the anti-bit balling additive comprises a C15-C18 alkene or a mixture of two or more C15-C18 alkenes. Methods for using the drilling fluid compositions may further include mixing the mixing an aqueous base fluid with one or more drilling fluid additives and an anti-bit balling additive, wherein the anti-bit balling additive includes a C15-C18 alkene or a mixture of two or more C15-C18 alkenes, and introducing the drilling fluid to a subterranean formation.

Abstract: Geopolymer cement slurries, cured geopolymer cements, and methods of making cured geopolymer cement and methods of using geopolymer cement slurries are provided. The geopolymer cement slurry comprises Saudi Arabian volcanic ash, an aqueous solution, Na2SiO3, NaOH, and a resin. The Saudi Arabian volcanic ash comprises SO3, CaO, SiO2, Al2O3, Fe2O3, MgO, and K2O.

Abstract: Geopolymer cement slurries, cured geopolymer cements, and methods of making cured geopolymer cement and methods of using geopolymer cement slurries are provided. The geopolymer cement slurry comprises cement precursor material, Saudi Arabian volcanic ash, and an aqueous solution. The Saudi Arabian volcanic ash comprises SO3, CaO, SiO2, Al2O3, Fe2O3, MgO, and K2O.

Abstract: A method of converting a drilling fluid into a geopolymer cement slurry includes introducing the drilling fluid into a wellbore, in which the drilling fluid comprises Na2SiO3, NaCl, or both. The method further includes introducing Saudi Arabian volcanic ash into the wellbore. The Saudi Arabian volcanic ash comprises SO3, CaO, SiO2, Al2O3, Fe2O3, MgO, and K2O. The method further includes allowing the Saudi Arabian volcanic ash to contact the drilling fluid in the wellbore, thereby converting the drilling fluid into the geopolymer cement slurry. A method of cementing a casing in a wellbore includes introducing a drilling fluid into a wellbore, in which the drilling fluid comprises Na2SiO3, NaCl, or both, and introducing Saudi Arabian volcanic ash into the wellbore to form the geopolymer cement slurry. The method further includes curing the geopolymer cement slurry to cement the casing in the wellbore.