Abstract: A composition containing a blend, reaction product, or mixture thereof, of (A) one or more hydrophobizing component or agent (e.g., an amine or amide containing compound), and (B) one or more phenolic material or composition comprising phenolic polymers or salts thereof (e.g., lignin, a lignin derivative, or mixture thereof), which may be utilized as a drilling fluid additive or as a component of a drilling fluid additive, is described. A method of making the composition or drilling fluid additive is also described. Further, a drilling fluid containing the drilling fluid additive or composition is described.

Abstract: An oil-based reservoir drill-in fluid (RDF) comprising an oil-based RDF additive that includes a blend, reaction product, or mixture thereof, of (A) one or more hydrophobizing component or agent (e.g., an amine or amide containing compound), and (B) one or more phenolic material or composition comprising phenolic polymers or salts thereof (e.g., lignin, a lignin derivative, or mixture thereof), which may be utilized as an oil-base RDF additive or as a component of an oil-based RDF additive, is described. A method of drilling a reservoir section of a wellbore with the oil-based RDF, the method including the oil-based RDF additive.

Abstract: A low gravity solid tolerant emulsifier and methods of making the same. The emulsifier includes a maleated amido-amine reaction product produced by: (1) reacting a fatty acid material comprising, and an amine material (e.g., a amine having a amine value of about 700 to about 1300 mg/g, such as AMINE HST) to produce an amido-amine reaction product; and (2) reacting the amido-amine reaction product with maleic anhydride to produce the maleated amido-amine reaction product. An invert emulsion fluids and drilling fluids that include the emulsifier of described herein and methods of using the same.

Abstract: The present disclosure provides a low gravity solid tolerant emulsifier and methods of making the same. The emulsifier includes a maleated amido-amine reaction product produced by: (1) reacting a fatty acid material comprising, and an amine material (e.g., a amine having a amine value of about 700 to about 1300 mg/g, such as AMINE HST) to produce an amido-amine reaction product; and (2) reacting the amido-amine reaction product with maleic anhydride to produce the maleated amido-amine reaction product. The present disclosure further provides invert emulsion fluids and drilling fluids that include the emulsifier of the present disclosure and methods of using the same.

Abstract: A low gravity solid tolerant emulsifier and methods of making the same is provided. The emulsifier includes a maleated amido-amine reaction product produced by: (1) reacting a fatty acid material including rosin acid at a concentration of about 11% to about 50%, and an amine material (e.g., a amine having a amine value of about 700 to about 1300 mg/g, such as AMINE HST) to produce an amido-amine reaction product; and (2) reacting the amido-amine reaction product with maleic anhydride to produce the maleated amido-amine reaction product. Invert emulsion fluids and drilling fluids that include the emulsifier above and methods of using the same is further provided.

Abstract: A composition containing a blend, reaction product, or mixture thereof, of (A) one or more hydrophobizing component or agent (e.g., an amine or amide containing compound), and (B) one or more phenolic material or composition comprising phenolic polymers or salts thereof (e.g., lignin, a lignin derivative, or mixture thereof), which may be utilized as a drilling fluid additive or as a component of a drilling fluid additive, is described. A method of making the composition or drilling fluid additive is also described. Further, a drilling fluid containing the drilling fluid additive or composition is described.

Abstract: The present disclosure provides a low gravity solid tolerant emulsifier and methods of making the same. The emulsifier includes a maleated amido-amine reaction product produced by: (1) reacting a low titer fatty acid material comprising rosin acid, and an amine material (e.g., a amine having a amine value of about 700 to about 1300 mg/g, such as AMINE HST) to produce an amido-amine reaction product; and (2) reacting the amido-amine reaction product with maleic anhydride to produce the maleated amido-amine reaction product. The present disclosure further provides invert emulsion fluids and drilling fluids that include the emulsifier of the present disclosure and methods of using the same.

Abstract: An invert emulsion treatment fluid comprises: (A) an external phase, wherein the external phase comprises a hydrocarbon liquid; (B) an internal phase, wherein the internal phase comprises a hygroscopic liquid; (C) a suspending agent, wherein the suspending agent is a polymer, and wherein the polymer comprises urea linkages; and (D) a particulate, wherein the particulate has a density less than 3.5 g/cm3, wherein a test fluid consisting essentially of the external phase, the internal phase, the suspending agent, and the particulate, and in the same proportions as the treatment fluid, and after static aging for 2 months at a temperature of 200° F. (93.3° C.), has a 10 minute gel strength of at least 30 lb/100 ft2 (1,436 Pa) at a temperature of 120° F. (48.9° C.). A method of using the invert emulsion treatment fluid comprises: introducing the treatment fluid into a portion of a subterranean formation.

Abstract: An apparatus and method for determining a formation/fluid interaction of a target formation and a target drilling fluid is described herein. The method may include training an artificial neural network using a training data set. The training data set may include a formation characteristic of a source formation and a fluid characteristic of a source drilling fluid and experimental data on source formation/fluid interaction. Once the artificial neural network is trained, a formation characteristic of the target formation and fluid characteristic of target drilling fluid may be input. The formation characteristic of the target formation may correspond to the formation characteristic of the source formation. The fluid characteristic of the target drilling fluid may correspond to the fluid characteristic of the source drilling fluid. A formation/fluid interaction of the target formation and the target drilling fluid may be determined using a value output by the artificial neural network.

Abstract: A method of servicing a wellbore comprises determining a cation exchange capacity of a sample of a shale, determining a swelling characteristic of the shale using the cation exchange capacity in an equation comprising a term of the form: Az % salt=x(cation exchange capacity)y where Az % salt is a final swelling volume of the shale in the presence of an aqueous fluid having a salt concentration of z %, and x and y are empirical constants, determining a composition of a wellbore servicing fluid based on the determined swelling characteristic, and drilling the wellbore using the wellbore servicing fluid.

Abstract: An invert emulsion treatment fluid comprises: (A) an external phase, wherein the external phase comprises a hydrocarbon liquid; (B) an internal phase, wherein the internal phase comprises a hygroscopic liquid; (C) a suspending agent, wherein the suspending agent is a polymer, and wherein the polymer comprises urea linkages; and (D) a particulate, wherein the particulate has a density less than 3.5 g/cm3, wherein a test fluid consisting essentially of the external phase, the internal phase, the suspending agent, and the particulate, and in the same proportions as the treatment fluid, and after static aging for 2 months at a temperature of 200° F. (93.3° C.), has a 10 minute gel strength of at least 30 lb/100 ft2 (1,436 Pa) at a temperature of 120° F. (48.9° C.). A method of using the invert emulsion treatment fluid comprises: introducing the treatment fluid into a portion of a subterranean formation.

Abstract: An invert emulsion treatment fluid comprises: (A) an external phase, wherein the external phase comprises a hydrocarbon liquid; (B) an internal phase, wherein the internal phase comprises a hygroscopic liquid; (C) a suspending agent, wherein the suspending agent is a polymer, and wherein the polymer comprises urea linkages; and (D) a particulate, wherein the particulate has a density less than 3.5 g/cm3, wherein a test fluid consisting essentially of the external phase, the internal phase, the suspending agent, and the particulate, and in the same proportions as the treatment fluid, and after static aging for 2 months at a temperature of 200° F. (93.3° C.), has a 10 minute gel strength of at least 30 lb/100 ft2 (1,436 Pa) at a temperature of 120° F. (48.9° C.). A method of using the invert emulsion treatment fluid comprises: introducing the treatment fluid into a portion of a subterranean formation.

Abstract: An apparatus and method for determining a formation/fluid interaction of a target formation and a target drilling fluid is described herein. The method may include training an artificial neural network using a training data set. The training data set may include a formation characteristic of a source formation and a fluid characteristic of a source drilling fluid and experimental data on source formation/fluid interaction. Once the artificial neural network is trained, a formation characteristic of the target formation and fluid characteristic of target drilling fluid may be input. The formation characteristic of the target formation may correspond to the formation characteristic of the source formation. The fluid characteristic of the target drilling fluid may correspond to the fluid characteristic of the source drilling fluid. A formation/fluid interaction of the target formation and the target drilling fluid may be determined using a value output by the artificial neural network.

Abstract: A method of servicing a wellbore comprises determining a cation exchange capacity of a sample of a shale, determining a swelling characteristic of the shale using the cation exchange capacity in an equation comprising a term of the form: Az% salt=x(cation exchange capacity)y where Az% salt is a final swelling volume of the shale in the presence of an aqueous fluid having a salt concentration of z %, and x and y are empirical constants, determining a composition of a wellbore servicing fluid based on the determined swelling characteristic, and drilling the wellbore using the wellbore servicing fluid.

Abstract: An invert emulsion treatment fluid comprises: (A) an external phase, wherein the external phase comprises a hydrocarbon liquid; (B) an internal phase, wherein the internal phase comprises a hygroscopic liquid; (C) a suspending agent, wherein the suspending agent is a polymer, and wherein the polymer comprises urea linkages; and (D) a particulate, wherein the particulate has a density less than 3.5 g/cm3, wherein a test fluid consisting essentially of the external phase, the internal phase, the suspending agent, and the particulate, and in the same proportions as the treatment fluid, and after static aging for 2 months at a temperature of 200° F. (93.3 ° C.), has a 10 minute gel strength of at least 30 lb/100 ft2 (1,436 Pa) at a temperature of 120° F. (48.9° C.). A method of using the invert emulsion treatment fluid comprises: introducing the treatment fluid into a portion of a subterranean formation.

Abstract: Of the many compositions and methods provided here, one method includes providing a drilling fluid comprising a lost circulation material and a base drilling fluid, wherein the base drilling fluid comprises an oleaginous continuous phase and a polar organic molecule, wherein the base drilling fluid has a first normal stress difference magnitude (|N1|) greater than about 100 Pa; and drilling a portion of a wellbore in a subterranean formation using the drilling fluid.