Abstract: A method of using an aqueous-based drilling fluid comprises: introducing the drilling fluid into a wellbore, wherein the wellbore penetrates a subterranean formation, wherein the drilling fluid comprises: (A) a base fluid, wherein the base fluid comprises water; and (B) a shale stabilizer additive, wherein the shale stabilizer additive: (i) is made from a protein; (ii) is food grade; and (iii) provides a shale retention of at least 85% for the subterranean formation.

Abstract: Compositions and methods for formulating lost circulation materials are provided. More particularly, in certain embodiments, the present disclosure relates to drilling fluids that comprise chitosan flakes as a lost circulation material. In one embodiment, the method comprises: introducing a drilling fluid into a wellbore penetrating at least a portion of a subterranean formation, wherein the drilling fluid comprises: a base fluid; and a lost circulation material comprising chitosan flakes; and forming a filter cake or LCM plug with the chitosan flakes in at least a portion of the subterranean formation.

Abstract: A method of using an aqueous-based drilling fluid comprises: introducing the drilling fluid into a wellbore, wherein the wellbore penetrates a subterranean formation, wherein the drilling fluid comprises: (A) a base fluid, wherein the base fluid comprises water; and (B) a shale stabilizer additive, wherein the shale stabilizer additive: (i) is made from a protein; (ii) is food grade; and (iii) provides a shale retention of at least 85% for the subterranean formation.

Abstract: A treatment fluid comprises: water; a carboxylate; and a corrosion inhibitor, wherein the corrosion inhibitor is a polymer, wherein the polymer comprises silicone, an ether monomer residue, and an amine functional group; wherein a test fluid consisting essentially of the water, the carboxylate, and the corrosion inhibitor, and in the same proportions as in the treatment fluid, is capable of providing a corrosion weight loss to a metal plate of less than 0.05 pounds per square feet (lb/ft2) under testing conditions of 200° F. (93.3° C.), a pressure of 500 psi (3.4 MPa), and a time of 24 hours whereas a substantially identical test fluid without the corrosion inhibitor provides a corrosion weight loss of greater than 0.05 lb/ft2 under the testing conditions. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well.

Abstract: A treatment fluid comprises: water; a carboxylate; and a corrosion inhibitor, wherein the corrosion inhibitor is environmentally-friendly, biodegradable, and is a polymer, wherein the polymer comprises a carbohydrate backbone and a quaternary amine functional group; wherein a test fluid consisting essentially of the water, the carboxylate, and the corrosion inhibitor, and in the same proportions as in the treatment fluid, is capable of providing a corrosion weight loss to a metal plate of less than 0.05 pounds per square feet (lb/ft2) under testing conditions of 200° F. (93.3° C.), a pressure of 500 psi (3.4 MPa), and a time of 24 hours whereas a substantially identical test fluid without the corrosion inhibitor provides a corrosion weight loss of greater than 0.05 lb/ft2 under the testing conditions. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well.

Abstract: A treatment fluid comprises: water; a carboxylate; and a corrosion inhibitor, wherein the corrosion inhibitor is a polymer, wherein the polymer comprises silicone, an ether monomer residue, and an amine functional group; wherein a test fluid consisting essentially of the water, the carboxylate, and the corrosion inhibitor, and in the same proportions as in the treatment fluid, is capable of providing a corrosion weight loss to a metal plate of less than 0.05 pounds per square feet (lb/ft2) under testing conditions of 200° F. (93.3° C.), a pressure of 500 psi (3.4 MPa), and a time of 24 hours whereas a substantially identical test fluid without the corrosion inhibitor provides a corrosion weight loss of greater than 0.05 lb/ft2 under the testing conditions. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well.