Salt-tolerant, thermally-stable rheology modifiers

1. A method of drilling a wellbore through a subterranean rock formation comprising:

providing a drilling fluid comprising an aqueous base fluid, a weight material, and between 0.5 g/l and 24 g/l (0.175 ppb and 8.4 ppb) (on an active basis) of a rheology modifier comprising a terpolymer of acrylamide, 2-acrylamido-2-methyl-propanesulfonic acid (AMPS) and a long-chain alkyl acrylate having a chain length for the alkyl group of from 12-25 wherein said terpolymer is made through a dispersion polymerization process and a saturated KCI or NaCl solution containing 1% by weight of the terpolymer has a Brookfield viscosity of about 400 cps or more at 20° C.;

pumping said drilling fluid down tubing in the wellbore and through nozzles in a drilling bit attached to the bottom end of the tubing while rotating the bit to detach cuttings from the rock formation;

transporting the cuttings up the annulus between the tubing and the wellbore wall, the cuttings transport being facilitated by the flow of rheology-modified drilling fluid.

2. A method of completing a wellbore that penetrates through a porous and permeable subterranean rock formation comprising:

providing a completion fluid comprising an aqueous base fluid, a weight material that is a density-increasing soluble salt and/or an insoluble particulate weight material, and between 0.5 g/l and 24 g/l (0.175 ppb and 8.4 ppb) of a salt-tolerant, thermally-stable rheology modifier comprising a terpolymer of acrylamide, 2-acrylamido-2-methyl-propanesulfonic acid (AMPS) and a long-chain alkyl acrylate having a chain length for the alkyl group of from 12-25, wherein said terpolymer is made through a dispersion polymerization process and a saturated KCI or NaCl solution containing 1% by weight of the terpolymer has a Brookfield viscosity of about 400 cps or more at 200° C.;

pumping said completion fluid into the wellbore so that the formation fluid pressure and/or losses of completion fluid to the formation are controlled; and

performing the operations required to complete the well.

3. A method of fracturing a rock formation comprising:

injecting a fracturing fluid into an interval of a wellbore across the rock formation that is to be fractured wherein the fracturing fluid comprises an aqueous base fluid, optionally a proppant, and a salt-tolerant thermally-stable rheology modifier comprising a terpolymer of acrylamide, 2-acrylamido-2-methyl-propanesulfonic acid (AMPS) and a long-chain alkyl acrylate having a chain length for the alkyl group of from 12-25, wherein said terpolymer is made through a dispersion polymerization process and a saturated KCI or NaCl solution containing 1% by weight of the terpolymer has a Brookfield viscosity of about 400 cps or more at 20° C.; at a dose of between about 0.5 g/l (about 4 lbs per 1,000 US gallons) and about 6.25 gn (about 50 lbs per 1,000 US gallons); and

maintaining the pressure of the fracturing fluid at above the fracture pressure of the formation whereby the fractures grow and the rheology modifier solution assists the transport of any proppant particles along the fractures and reduces the rate of leak-off of the fluid into the rock formation.

4. A method of fracturing a rock formation as in claim 3 wherein the fracturing fluid comprises a cross-linking agent to increase viscosity and gel strength of the fracturing fluid.

5. A method of fracturing a rock formation comprising:

injecting a fracturing fluid into an interval of a wellbore across the rock formation that is to be fractured wherein the fracturing fluid comprises an aqueous base fluid, optionally a proppant, and a salt-tolerant, thermally-stable rheology modifier comprising a terpolymer of acrylamide, 2-acrylamido-2-methyl-propanesulfonic acid (AMPS) and a long-chain alkyl acrylate having a chain length for the alkyl group from 12-25, wherein said terpolymer is made through a dispersion polymerization process and a saturated KCI or NaCl solution containing 1% by weight of the terpolymer has a Brookfield viscosity of about 400 cps or more at 20° C.; at a dose of between about 0.001 g/l (about 0.08 lbs per 1,000 US gallons) and about 0.5 g/l (about 4 lbs per 1,000 US gallons);

maintaining the pressure of the fracturing fluid at above the fracture pressure of the formation by pumping at a sufficiently high rate.

6. A method of fracturing a rock formation of claim 5 , wherein the rheology modifier is added to the fracturing fluid in the form of an aqueous dispersion polymer or an emulsion polymer suspended in an oleaginous liquid.