Abstract: Described is a method for assessing quality of an amine-based shale inhibitor in drilling fluid. A relationship between a concentration of the amine-based shale inhibitor in a drilling fluid and turbidity is established by preparing drilling fluid solutions with varying concentrations of the amine-based shale inhibitor, allowing the drilling fluid solutions to form precipitates, and analyzing turbidity of the drilling fluid solutions. A sample of a drilling fluid with an unknown concentration of amine-based shale inhibitor is obtained. Using the established relationship, a concentration of the amine-based shale inhibitor in the sample of the drilling fluid is estimated.

Abstract: A wellbore fluid composition is provided that includes an aqueous base fluid and at least one ethylene ammonium salt having a number average molecular weight in a range of 250 to 500 grams per mole. A method of drilling a wellbore is also provided. the method includes circulating an aqueous drilling fluid into the wellbore while drilling, wherein the aqueous drilling fluid includes at least one ethylene ammonium salt. The aqueous drilling fluid further includes a pH value from 6.5 to 7.5. The method of drilling a wellbore further includes recovering shale cuttings while maintaining wellbore stability.

Abstract: A wellbore fluid composition is provided that includes an aqueous base fluid and at least one ethylene ammonium salt having a number average molecular weight in a range of 250 to 500 grams per mole. A method of drilling a wellbore is also provided. the method includes circulating an aqueous drilling fluid into the wellbore while drilling, wherein the aqueous drilling fluid includes at least one ethylene ammonium salt. The aqueous drilling fluid further includes a pH value from 6.5 to 7.5. The method of drilling a wellbore further includes recovering shale cuttings while maintaining wellbore stability.

Abstract: Water-based drilling fluids may include an aqueous base fluid and a mixture of polyethylene polyamines in an amount of from 1 lbm/bbl to 20 lbm/bbl relative to the total volume of the water-based drilling fluid. The polyethylene polyamines of the mixture may have a first chemical structure H2NCH2CH2(NHCH2CH2)xNH2, where x may be an integer greater than or equal to 3. The average molecular weight of the polyethylene polyamines in the water-based drilling fluid having the first chemical structure may be from 200 g/mol to 400 g/mol. Methods for drilling a subterranean well with the water-based drilling fluids are also disclosed.

Abstract: According to one or more embodiments of the present disclosure, water-based drilling fluids may include an aqueous base fluid and one or more additives. In embodiments, water-based drilling fluids may include a lubricant blend including at least oleic acid and palmitoleic acid. The sum of the volume percent of the oleic acid and palmitoleic acid may be from 0.1 vol. % to 10 vol. % of the total volume of the water-based drilling fluid. In embodiments, water-based drilling fluids may include a lesser melting point fraction of jojoba oil in an amount of from 0.1 vol. % to 10 vol. % relative to the total volume of the water-based drilling fluid. At least 90% of the lesser melting point fraction of jojoba oil may have a melting point less than or equal to 15° C. Methods for drilling subterranean wells with the water-based drilling fluids are also disclosed.

Abstract: Water-based drilling fluids may include an aqueous base fluid and a mixture of polyethylene polyamines in an amount of from 1 lbm/bbl to 20 lbm/bbl relative to the total volume of the water-based drilling fluid. The polyethylene polyamines of the mixture may have a first chemical structure H2NCH2CH2(NHCH2CH2)xNH2, where x may be an integer greater than or equal to 3. The average molecular weight of the polyethylene polyamines in the water-based drilling fluid having the first chemical structure may be from 200 g/mol to 400 g/mol. Methods for drilling a subterranean well with the water-based drilling fluids are also disclosed.

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 invert-emulsion drilling fluid may include a dispersed aqueous phase including an aqueous base fluid, a continuous non-aqueous phase including a non-aqueous base fluid, and a first bridging package. The first bridging package may include one or more particulate carbonate materials. All of the particulate carbonate materials of the invert-emulsion drilling fluid may be part of the first bridging package. The first bridging package may have a trimodal particle size distribution such that the particle size distribution of the first bridging package includes three peaks, wherein each peak may be in the range of less than or equal to 300 microns in the particle size distribution. The invert-emulsion drilling fluid may be included in methods for reducing lost circulation in subterranean formations during drilling operations.

Abstract: Provided is a lost circulation material that may consist essentially of an alkaline nanosilica dispersion and a sodium bicarbonate activator. Further provided are methods that may control lost circulation in a lost circulation zone in a wellbore by introducing the lost circulation material such that it contacts the lost circulation zone and forms a gelled solid in the lost circulation zone.

Abstract: According to one or more embodiments of the present disclosure, water-based drilling fluids may include an aqueous base fluid and one or more additives. In embodiments, water-based drilling fluids may include a lubricant blend including at least oleic acid and palmitoleic acid. The sum of the volume percent of the oleic acid and palmitoleic acid may be from 0.1 vol. % to 10 vol. % of the total volume of the water-based drilling fluid. In embodiments, water-based drilling fluids may include a lesser melting point fraction of jojoba oil in an amount of from 0.1 vol. % to 10 vol. % relative to the total volume of the water-based drilling fluid. At least 90% of the lesser melting point fraction of jojoba oil may have a melting point less than or equal to 15° C. Methods for drilling subterranean wells with the water-based drilling fluids are also disclosed.

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: Provided is a lost circulation material that may consist essentially of an alkaline nanosilica dispersion and a sodium bicarbonate activator. Further provided are methods that may control lost circulation in a lost circulation zone in a wellbore by introducing the lost circulation material such that it contacts the lost circulation zone and forms a gelled solid in the lost circulation zone.

Abstract: An invert-emulsion drilling fluid may include a dispersed aqueous phase including an aqueous base fluid, a continuous non-aqueous phase including a non-aqueous base fluid, and a first bridging package. The first bridging package may include one or more particulate carbonate materials. All of the particulate carbonate materials of the invert-emulsion drilling fluid may be part of the first bridging package. The first bridging package may have a trimodal particle size distribution such that the particle size distribution of the first bridging package includes three peaks, wherein each peak may be in the range of less than or equal to 300 microns in the particle size distribution. The invert-emulsion drilling fluid may be included in methods for reducing lost circulation in subterranean formations during drilling operations.

Abstract: According to one or more embodiments of the present disclosure, water-based drilling fluids may include an aqueous base fluid and one or more additives. In embodiments, water-based drilling fluids may include a lubricant blend including at least oleic acid and palmitoleic acid. The sum of the volume percent of the oleic acid and palmitoleic acid may be from 0.1 vol. % to 10 vol. % of the total volume of the water-based drilling fluid. In embodiments, water-based drilling fluids may include a lesser melting point fraction of jojoba oil in an amount of from 0.1 vol. % to 10 vol. % relative to the total volume of the water-based drilling fluid. At least 90% of the lesser melting point fraction of jojoba oil may have a melting point less than or equal to 15° C. Methods for drilling subterranean wells with the water-based drilling fluids are also disclosed.

Abstract: According to one or more embodiments of the present disclosure, water-based drilling fluids may include an aqueous base fluid and one or more additives. In embodiments, water-based drilling fluids may include a lubricant blend including at least oleic acid and palmitoleic acid. The sum of the volume percent of the oleic acid and palmitoleic acid may be from 0.1 vol. % to 10 vol. % of the total volume of the water-based drilling fluid. In embodiments, water-based drilling fluids may include a lesser melting point fraction of jojoba oil in an amount of from 0.1 vol. % to 10 vol. % relative to the total volume of the water-based drilling fluid. At least 90% of the lesser melting point fraction of jojoba oil may have a melting point less than or equal to 15° C. Methods for drilling subterranean wells with the water-based drilling fluids are also disclosed.

Abstract: Various invert emulsion drilling fluid compositions. One such invert emulsion drilling fluid is a water in oil emulsion, which can include an invert emulsifier to stabilize the water in oil emulsion, a C16 to C18 saturated linear alpha carboxylic acid, a fatty dimer diamine, a filtration control agent, a weighting agent including manganese tetroxide, and a bridging agent including calcium chloride. The invert emulsion drilling fluids can be formulated to be substantially free of clay.

Abstract: Provided here are various invert emulsion drilling fluid compositions. One such invert emulsion drilling fluid is a water in oil emulsion, which can include an invert emulsifier to stabilize the water in oil emulsion, a C16 to C18 saturated linear alpha carboxylic acid, a fatty dimer diamine, a filtration control agent, a weighting agent including manganese tetroxide, and a bridging agent including calcium chloride. The invert emulsion drilling fluids can be formulated to be substantially free of clay.