High temperature hydraulic fracturing fluid

• US 6,227,295 B1
• Filed: 10/08/1999
• Issued: 05/08/2001
• Est. Priority Date: 10/08/1999
• Status: Expired due to Term

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Mitchell, Thomas O., Parris, Michael D.
• Primary Examiner(s): SUCHFIELD, GEORGE A
• Application Number:
  US09/415,400
• Time in Patent Office: 578 Days
• Field of Search: 166/300, 166/308, 507/211, 507/213, 507/215, 507/216, 507/217, 507/246, 507/248, 507/250, 507/251, 507/271, 507/273, 507/903, 507/922
• US Class Current: 166/300
• CPC Class Codes: C09K 8/685 containing cross-linking agents
• CPC Class Codes: Y10S 507/903 Crosslinked resin or polymer
• CPC Class Codes: Y10S 507/922 Fracture fluid

Abstract

A fluid that is useful in stimulation operations, and in particular, in hydraulic fracturing treatments, comprises a carrier fluid; a solvatable, crosslinkable polymer; a cross-linking agent that does not cause substantial cross-linking of the polymer at temperatures less than about 105° F. and a pH of about 10 or greater; and an organic amine stabilizing agent that has a first pK_a or a pH in water of at least about 9.5. One group of such amines has the formula

H₂N—(R₁NH)_n—H

where R₁ is C₁-C₄ alkyl and n is from 1-6. In one embodiment, the cross-linking agent is an organic zirconate, such as bis(hydroxyethyl)glycine zirconate. The organic zirconate is effective to cross-link the polymer when the composition is at a temperature of at least about 105° F., and a pH of about 10 or higher, preferably a pH in the range of about 10.5-12.

Claims

1. A method of hydraulically fracturing a subterranean formation, comprising the step of:

injecting a well treatment fluid composition via a wellbore into a subterranean formation at a flow rate and pressure sufficient to produce or extend a fracture in the formation, wherein the well treatment fluid composition comprises;

a carrier fluid;

a solvatable, crosslinkable polymer;

a cross-linking agent that does not cause substantial cross-linking of the polymer at temperatures less than about 105°

F. and a pH of about 10 or greater; and

an organic amine stabilizing agent that has a first pK_a or a pH in water of at least about 9.5.

2. The method of claim 1, wherein the cross-linking agent is an organic zirconate.

3. The method of claim 2, wherein the organic zirconate cross-linking agent is effective to cross-link the polymer at a pH of about 10 or higher and a temperature of at least about 105°

F.

4. The method of claim 3, wherein the organic zirconate cross-linking agent is effective to cross-link the polymer at a pH in the range of about 10.5-12 and a temperature of at least about 105°

F.

5. The method of claim 1, wherein the cross-linking agent comprises bis(hydroxyethyl)glycine zirconate.

6. The method of claim 1, wherein the organic amine has from 1-20 carbon atoms.

7. The method of claim 1, wherein the organic amine has the formula

8. The method of claim 7, wherein R₁ is ethylene.

9. The method of claim 8, wherein the stabilizing agent comprises tetraethylenepentamine.

10. The method of claim 1, wherein the polymer is selected from the group consisting of guar, hydroxypropyl guar, carboxymethyl guar, carboxymethylhydroxypropyl guar, hydroxyethyl cellulose, carboxymethylhydroxyethyl cellulose, hydroxypropyl cellulose, xanthan, and mixtures thereof.

11. The method of claim 1, wherein the fluid further comprises a proppant.

12. The method of claim 1, wherein the fluid further comprises a delay agent.

13. The method of claim 12, wherein the delay agent is a bicarbonate salt.

14. The method of claim 1, wherein the fluid further comprises a viscosity breaker agent.

15. The method of claim 1, wherein the fluid further comprises at least one additive selected from the group consisting of scale inhibitors, surfactants, biocides, and breaker aids.

16. A method of hydraulically fracturing a subterranean formation, comprising the step of:

injecting a well treatment fluid composition via a wellbore into a subterranean formation at a flow rate and pressure sufficient to produce or extend a fracture in the formation, wherein the well treatment fluid composition comprises;

a carrier fluid;

a solvatable, crosslinkable polymer selected from the group consisting of guar, hydroxypropyl guar, carboxymethyl guar, carboxymetylhydroxypropyl guar, hydroxyethyl cellulose, carboxymethylhydroxyethyl cellulose, hydroxypropyl cellulose, xanthan, and mixtures thereof;

a cross-linking agent that comprises bis(hydroxyethyl)glycine zirconate;

an organic amine stabilizing agent that comprises tetraethylenepentamine; and

a delay agent that comprises a bicarbonate salt.

17. The method of claim 16, wherein the fluid further comprises a viscosity breaker agent.