Cationic and anionic shale inhibitors and clay stabilizers
Compositions and methods of using of such compositions to, for example, inhibit shale are provided. In one embodiment, the methods include introducing an additive including a cationic clay stabilizer and an anionic clay stabilizer into a treatment fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation. In some embodiments, the methods include introducing an additive including a cationic shale inhibitor and an anionic shale inhibitor into a treatment fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.
1. A method of fracture stimulation comprising:
introducing an anionic friction reducer and an additive comprising a salt, a cationic shale inhibitor, and an anionic shale inhibitor into a treatment fluid, wherein the cationic shale inhibitor is present in the additive at a ratio of about 1:2 to about 1:5 by volume of the anionic shale inhibitor,
wherein the cationic shale inhibitor is selected from the group consisting of:
polydiallyldimethylammonium chloride; a cationic polyamine; a quaternary ammonium salt; and any combination thereof,
wherein the anionic shale inhibitor is selected from the group consisting of: polyacrylamide polymer, copolymer, or terpolymer; polyacrylic acid; polyacrylamide copolymer; a block copolymer of polyacrylamide and 2-acrylamido-2-methylpropane sulfonic acid (AMPS); 2-acrylamido-tertbutylsulfonic acid (ATBS); poly(acrylamide-co-acrylic acid); and any combination thereof;
wherein the salt is selected from the group consisting of: calcium chloride, sodium chloride, potassium chloride, calcium bromine, ammonium chloride, ammonium nitrate, sodium acetate, and any combination thereof;
wherein the cationic shale inhibitor is present in the additive in an amount of about 2% to about 5% by weight of the additive;
introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation that comprises shale at or above a pressure sufficient to create or enhance one or more fractures in the subterranean formation; and
allowing the additive to interact with the shale in the subterranean formation to at least partially inhibit the shale.
2. The method of claim 1 , wherein the cationic shale inhibitor comprises a cationic polyamine having a molecular weight of from about 1,000 g/mol to about 200,000 g/mol.
3. The method of claim 1 , wherein the treatment fluid is introduced into at least a portion of the wellbore or subterranean formation having a temperature of 150° F. or higher.
4. The method of claim 1 , wherein the additive is added to the treatment fluid in an amount of from about 0.01 to about 10 gallons per thousand gallons by volume of the treatment fluid.
5. The method of claim 1 , wherein the cationic shale inhibitor is present in the additive in an amount of from about 1% to about 10% by weight of the additive.
6. A method of fracture stimulation comprising:
introducing a treatment fluid into a wellbore penetrating at least a portion of a subterranean formation that comprises clay at or above a pressure sufficient to create or enhance one or more fractures in the subterranean formation, wherein the treatment fluid comprises:
a base fluid;
proppant;
an anionic friction reducer; and
an additive comprising a salt, a cationic clay stabilizer, and an anionic clay stabilizer,
wherein the cationic clay stabilizer is selected from the group consisting of:
polydiallyldimethylammonium chloride; a cationic polyamine; a quaternary ammonium salt; and any combination thereof;
wherein the anionic clay stabilizer is selected from the group consisting of:
polyacrylamide polymer, copolymer, or terpolymer; polyacrylic acid; polyacrylamide copolymer; a block copolymer of polyacrylamide and 2-acrylamido-2-methylpropane sulfonic acid (AMPS); 2-acrylamido-tertbutylsulfonic acid (ATBS); poly(acrylamide-co-acrylic acid); and any combination thereof;
wherein the salt is selected from the group consisting of: calcium chloride, sodium chloride, potassium chloride, calcium bromine, ammonium chloride, ammonium nitrate, sodium acetate, and any combination thereof;
wherein the cationic shale inhibitor is present in the additive in an amount of about 2% to about 5% by weight of the additive; and
allowing the additive to interact with the clay in the subterranean formation to at least partially inhibit the clay.
7. The method of claim 6 , wherein the cationic clay stabilizer comprises a cationic polyamine having a molecular weight of from about 1,000 g/mol to about 200,000 g/mol.
8. The method of claim 6 , wherein the treatment fluid is introduced into at least a portion of the wellbore or subterranean formation having a temperature of 150° F. or higher.
9. A method of fracture stimulation comprising:
introducing an additive comprising a salt, a cationic shale inhibitor, and an anionic shale inhibitor into a treatment fluid, wherein the cationic shale inhibitor is present in the additive at a ratio of about 1:2 to about 1:5 by volume of the anionic shale inhibitor,
wherein the cationic shale inhibitor is selected from the group consisting of:
polydiallyldimethylammonium chloride; a cationic polyamine; a quaternary ammonium salt; and any combination thereof;
wherein the anionic shale inhibitor is selected from the group consisting of:
polyacrylamide polymer, copolymer, or terpolymer; polyacrylic acid; polyacrylamide copolymer; a block copolymer of polyacrylamide and 2-acrylamido-2-methylpropane sulfonic acid (AMPS); 2-acrylamido-tertbutyl sulfonic acid (ATBS); poly(acrylamide-co-acrylic acid); and any combination thereof;
wherein the salt is selected from the group consisting of: calcium chloride, sodium chloride, potassium chloride, calcium bromine, ammonium chloride, ammonium nitrate, sodium acetate, and any combination thereof;
wherein the cationic shale inhibitor is present in the additive in an amount of about 2% to about 5% by weight of the additive;
introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation that comprises shale at or above a pressure sufficient to create or enhance one or more fractures in the subterranean formation; and
allowing the additive to interact with the shale in the subterranean formation having a temperature of 150° F. or higher to at least partially inhibit the shale.