High temperature fracturing fluids and method of use
A treatment fluid for treating a subterranean formation is formed from an aqueous solution of a polysaccharide, a polyacrylamide, a crosslinking agent, which may be a Group 4 transition metal crosslinking agent, and less than 0.1% by weight of any clay component. In certain embodiments, the polyacrylamide may have an average molecular weight of from greater than 0.5 million to about 20 million and may be present in the fluid in an amount of from about 0.01% to 1% by weight of the fluid. A method of treating a subterranean formation penetrated by a wellbore may be carried out by introducing the treatment fluid into the formation through the wellbore. In certain embodiments, the treatment fluid may be introduced into a portion of the formation having a temperature of 120° C. or higher.
1. A method of treating a subterranean formation penetrated by a wellbore comprising:
introducing a treatment fluid into the formation through the wellbore comprising an aqueous solution of a polysaccharide, a polyacrylamide, and a crosslinking agent, wherein the polyacrylamide is present in an amount of from about 0.01% to about 1% by weight of the fluid and
wherein the polyacrylamide has an average molecular weight of from greater than 0.5 million to about 20 million.
2. The method of claim 1 , wherein: the polysaccharide is selected from carboxymethylhydroxypropyl guar (CMHPG), hydroxypropyl guar, guar and combinations of these.
3. The method of claim 1 , wherein: the polyacrylamide is a polyacrylamide homopolymer, a copolymer of acrylamide and acrylate monomers or a copolymer of acrylamide and other monomers.
4. The method of claim 1 , wherein: the polyacrylamide is a copolymer of acrylamide and acrylate monomers or other monomers and wherein the acrylate or other monomers comprise from about 0.1% to about 50% of the copolymer.
5. The method of claim 1 , wherein: the polysaccharide polymer is present in an amount of from about 0.1% or more by weight of the fluid.
6. The method of claim 1 , wherein: the crosslinking agent is a Group 4 transition metal crosslinking agent.
7. The method of claim 6 , wherein: the Group 4 transition metal crosslinking agent is selected from zirconium, titanium and hafnium crosslinking agents and is present in an amount of from about 0.01% to about 1.5% by weight of the fluid.
8. The method of claim 1 , wherein: introducing the treatment fluid into the formation through the wellbore is at a pressure above the fracture pressure of the formation.
9. The method of claim 1 , wherein: introducing the treatment fluid into the formation through the wellbore is at a viscosity of about 100 mPa-s or higher.
10. The method of claim 1 , wherein: introducing the treatment fluid into the formation through the wellbore includes introducing the treatment fluid into a portion of the formation having a temperature of 120° C. or higher.
11. The method of claim 1 , wherein: introducing the treatment fluid into the formation through the wellbore includes introducing the treatment fluid into a portion of the formation having a temperature of 230° C. or higher.
12. The method of claim 1 , wherein: the fluid further comprising less than 0.1% by weight of any clay component.
13. A method of treating a subterranean formation penetrated by a wellbore comprising:
introducing a treatment fluid into the formation through the wellbore comprising an aqueous solution of a polysaccharide, a polyacrylamide, a crosslinking agent, and less than 0.1% by weight of any clay component,
wherein the polyacrylamide is incorporated in amount to sufficiently enhance high temperature endurance of the fluid and
wherein the polyacrylamide has an average molecular weight of from greater than 0.5 million to about 20 million.