Method of using delayed hydratable polymeric viscosifying agent in the treatment of a well or subterranean formation
The disclosure relates to a method of delaying viscosification of a well treatment fluid within a well or within a subterranean formation penetrated by a well by introducing into the well a hydratable viscosifying agent of particulates having a minimum of 40% retention on a 60 mesh screen and a minimum of 1% retention on a 20 mesh screen.
1. A method of delaying viscosification of a well treatment fluid within a well or within a subterranean formation penetrated by a well, the method comprising introducing into the well or subterranean formation a well treatment fluid containing a crosslinkable hydratable polymeric viscosifying agent and a crosslinking agent or a non-crosslinkable hydratable polymeric viscosifying agent, wherein the hydratable polymeric viscosifying agent comprises particulates having a minimum of 40% retention on a 60 mesh screen and a minimum of 1% retention on a 20 mesh screen and wherein hydration of the hydratable polymeric viscosifying agent is delayed during either (i) stimulation of the well; (ii) a hydraulic fracturing operation of the subterranean formation; (iii) a drilling operation; or (iv) a sand control operation within the well and further wherein a linear gel forms in-situ from the non-crosslinkable polymeric viscosifying agent or a crosslinked gel forms in-situ from the crosslinkable hydratable polymeric viscosifying agent and crosslinking agent.
2. The method of claim 1 , wherein the hydratable polymeric viscosifying agent composed of particulates having a particle size which maintain a minimum of 60% retention on a 60 mesh screen.
3. The method of claim 1 , wherein the hydratable polymeric viscosifying agent is selected from the group consisting of a cellulosic derivative, a polyvinyl alcohol or an ammonium or alkali metal salt of an acrylamidomethylpropanesulfonic acid and mixtures thereof.
4. The method of claim 3 wherein the hydratable polymeric viscosifying agent is a cellulosic derivative selected from the group consisting of hydroxyethyl cellulose, methylhydroxyethyl cellulose, carboxymethylhydroxyethyl cellulose, hydroxyethylmethyl cellulose, ethylhydroxyethyl cellulose, ethylmethylhydroxyethyl cellulose, hydroxypropyl cellulose, hydroxyethylpropyl cellulose, dialkyl carboxymethyl cellulose, carboxymethylhydroxyethyl cellulose and carboxymethyl cellulose and mixtures thereof.
5. The method of claim 1 , wherein the fluid loss value for the well treatment fluid at a temperature from about 80° F. to about 160° F. is lower than a substantially similar fluid containing a hydratable polymeric viscosifying agent composed of particulates having a particle size which maintain less than 20% retention on a 60 mesh screen.
6. The method of claim 1 , wherein hydration of the hydratable polymeric viscosifying agent is delayed during stimulation of the well.
7. The method of claim 1 , wherein hydration of the hydratable polymeric viscosifying agent is delayed during a hydraulic fracturing operation of the subterranean formation.
8. The method of claim 1 , wherein hydration of the hydratable polymeric viscosifying agent is delayed during a drilling operation.
9. The method of claim 1 , wherein hydration of the hydratable polymeric viscosifying agent is delayed during a sand control operation within the well.
10. The method of claim 1 , wherein the hydratable polymeric viscosifying agent is non-crosslinkable and further wherein a linear gel is formed in-situ from the non-crosslinkable polymeric viscosifying agent.
11. A method of treating a well or a subterranean formation penetrated by a well comprising introducing into the well or subterranean formation a fluid containing a hydratable polymeric viscosifying agent composed of particulates having a particle size such that a minimum of 40% of the particulates are retained on a 60 mesh screen and wherein at least one of the following conditions prevails:
(a) the fluid is a fracturing fluid and is pumped into the subterranean formation during a hydraulic fracturing operation;
(b) the fluid is pumped into the subterranean formation during a sand control operation; or
(c) the fluid is a drilling fluid and is pumped into the well during a drilling operation
and further wherein the hydratable polymeric viscosifying agent, when introduced into the well is (i) a crosslinkable hydratable polymeric viscosifying agent and a crosslinking agent wherein a thickened crosslinked gel forms in-situ; or (ii) a non-crosslinkable hydratable polymeric viscosifying agent which forms in-situ a linear gel.
12. The method of claim 11 , wherein the fluid is a fracturing fluid and further wherein the particulates are selected from the group consisting of polyvinyl alcohol, an ammonium or alkali metal salt of an acrylamidomethylpropanesulfonic acid, hydroxyethyl cellulose, methylhydroxyethyl cellulose, carboxymethylhydroxyethyl cellulose, hydroxyethylmethyl cellulose, ethylhydroxyethyl cellulose, ethylmethylhydroxyethyl cellulose, hydroxypropyl cellulose, hydroxyethylpropyl cellulose, dialkyl carboxymethyl cellulose, carboxymethylhydroxyethyl cellulose and carboxymethyl cellulose and mixtures thereof.
13. The method of claim 11 , wherein the hydratable polymeric viscosifying agent is composed of particulates having a particle size which maintain a minimum of 50% retention on a 60 mesh screen.
14. The method of claim 13 , wherein the hydratable polymeric viscosifying agent is composed of particulates having a particle size which maintain a minimum of 60% retention on a 60 mesh screen.
15. The method of claim 11 , wherein the fluid is a fracturing fluid and wherein viscosification of the fracturing fluid within the formation is delayed by the presence of the hydratable polymeric viscosifying agent in the fracturing fluid.
16. The method of claim 11 , wherein the fluid is a drilling fluid and wherein viscosification of the drilling fluid during a drilling operation is delayed by the presence of the hydratable viscosifying agent.
17. The method of claim 11 , wherein the fluid is a fracturing fluid and pumped into the subterranean formation at a pressure sufficient to initiate or create a fracture and wherein viscosification of the fracturing fluid within the formation is more delayed than when a substantially similar well treatment fluid is pumped into the well, the substantially similar well treatment fluid containing a hydratable polymeric viscosifying agent composed of particulates having a particle size which maintain less than 20% retention on a 60 mesh screen.
18. The method of claim 11 , wherein the hydratable polymeric viscosifying agent is composed of particulates having a minimum of 1% retention on a 20 mesh screen.
19. The method of claim 11 , wherein the hydratable polymeric viscosifying agent is composed of particulates having more than 5% retention on a 20 mesh screen.
20. A method of delaying hydration or viscosification of a well treatment fluid within a well or within a subterranean formation penetrated by a well, the method comprising introducing into the well or subterranean formation a fracturing fluid containing proppant and a hydratable polymeric viscosifying agent composed of particulates having a particle size having a minimum of 40% retention on a 60 mesh screen and a minimum of 1% retention on a 20 mesh screen and wherein the hydratable polymeric viscosifying agent, when introduced into the well is a crosslinkable hydratable polymeric viscosifying agent and a crosslinking agent or a non-crosslinkable hydratable polymeric viscosifying agent and wherein the hydratable polymeric viscosifying agent carries the proppant into a created or enlarged fracture in the well and further wherein (i) a thickened crosslinked gel forms in-situ from the polymeric viscosifying agent and crosslinking agent or (ii), a linear gel is formed in-situ from the hydratable polymeric viscosifying agent.