Use of composites having deformable core and viscosifying agent coated thereon in well treatment operations

Patent metadata

Field	Value
Publication number	US-9637675-B2
Application number	US-201113302816-A
Country	US
Kind code	B2
Filing date	Nov 22, 2011
Priority date	Nov 22, 2011
Publication date	May 2, 2017
Grant date	May 2, 2017

Abstract

Loss of wellbore fluids (such as drilling fluids, completion fluids and workover fluids) into the flow passages of a subterranean formation may be reduced or eliminated by introducing into the wellbore in communication with the formation a composition containing a composite of a deformable core having a hardened coating which contains a viscosifying agent and, optionally, a crosslinking agent. The viscosity of the composition increases in-situ as the viscosifying agent, and optional crosslinking agent, disassociate from the deformable core and react. A fluid-impermeable barrier is thereby formed. The composites may also be used in spacers, well cements, workover and completion fluids as their need arises.

First claim

What is claimed is:

1. A method of treating a well in communication with a subterranean formation which comprises:
(A) introducing into the well a pumpable well treatment fluid comprising (i) a composite of a deformable core coated with a crosslinkable viscosifying agent and a crosslinking agent, wherein the crosslinking agent reacts with the coated crosslinkable viscosifying agent after being introduced into the well and after disassociation of the crosslinkable viscosifying agent and crosslinking agent from the deformable core; and (ii) a carrier fluid;
(B) disassociating the viscosifying agent and the crosslinking agent from the deformable core, increasing the viscosity of the well treatment fluid in-situ by disassociating the viscosifying agent and crosslinking agent from the deformable core and forming agglomerates of the deformable core after disassociation of the crosslinking agent and viscosifying agent; and
(C) forming a barrier within the formation or within the wellbore from the agglomerates of deformable core

wherein the barrier causes at least one of the following conditions to result:
(a) reduction in the permeability of the formation;
(b) mitigation of fluid loss into the formation; or
(c) reduction of fluid communication within the well and further wherein at least one of the following conditions prevail:
(i) the amount of crosslinking agent coated onto the deformable core is between from 0.001 to 2 percent based on the total weight of the deformable core, viscosifying agent and crosslinking agent; or
(ii) the amount of viscosifying agent coated onto the deformable core is between from about 0.1 to about 5 wt %, based on the total weight of deformable core and viscosifying agent.

2. The method of claim 1 , wherein the deformable core is porous.

3. The method of claim 1 , wherein the deformable core has an apparent specific gravity less than or equal to 2.45.

4. The method of claim 3 , wherein the deformable core has an apparent specific gravity less than or equal to 2.0.

5. The method of claim 4 , wherein the deformable core has an apparent specific gravity less than or equal to 1.75.

6. The method of claim 5 , wherein the deformable core has an apparent specific gravity less than or equal to 1.25.

7. The method of claim 1 , wherein the well treatment fluid is introduced into the well in the form of a loss circulation pill.

8. The method of claim 1 , wherein the deformable core further has coated thereon a hardened crosslinking delaying agent.

9. The method of claim 1 , wherein the well treatment fluid is prepared on the fly.

10. The method of claim 1 , wherein the viscosifying agent is selected from the group consisting of cellulose, cellulosic derivatives, starch, galactomannans, xanthan, welan, succinoglycan, scleroglucan, diutan, underivatized galactomannan gums, derivatized galactomannan gums and homo-, block or random polymers containing vinyl alcohol, acrylate, pyrrolidone, 2-acrylamido-2-methylpropane sulfonate, or acrylamide units, and mixtures thereof.

11. The method of claim 10 , wherein the viscosifying agent is selected from the group consisting of underivatized guar, derivatized guar, alkylcelluloses, hydroxyalkyl celluloses, alkylhydroxyalkyl celluloses, carboxyalkyl cellulose, and mixtures thereof.

12. The method of claim 11 , wherein the viscosifying agent is a guar derivative selected from the group consisting of guar gum, carboxymethyl guar, carboxymethylhydroxypropyl guar, hydroxypropyl guar, and mixtures thereof.

13. The method of claim 1 , wherein the crosslinking agent comprises at least one member selected from the group of borate releasers or an organometallic or organic complexed metal ion comprising at least one transition metal or alkaline earth metal ion.

14. The method of claim 1 , wherein the deformable core is a natural product selected from chipped, ground or crushed nut shells, seed shells, fruit pits, processed wood at least partially coated or hardened with a protective coating or modifying agent, a furan, furfuryl, phenol formaldehyde, phenolic epoxy, melamine formaldehyde resin, urethane resin, polystyrene divinylbenzene, polystyrene/vinyl/divinyl benzene, acrylate-based terpolymer or a mixture thereof.

15. A method of treating a well in communication with a subterranean formation which comprises:
(A) introducing into the well a pumpable well treatment fluid comprising (i) a composite of a deformable core coated with a viscosifying agent and a crosslinking agent; and (ii) a carrier fluid;
(B) increasing the viscosity of the well treatment fluid in-situ by disassociating the viscosifying agent and crosslinking agent from the deformable core and reacting the viscosifying agent and crosslinking agent in proximity to a targeted area in the well; and
(C) forming a barrier from the deformable core within the formation or within the well after disassociation of the viscosifying agent and crosslinking agent from the deformable core and after reaction of the viscosifying agent and crosslinking agent

wherein the barrier causes at least one of the following conditions to result:
(a) reduction in the permeability of the formation;
(b) mitigation of fluid loss into the formation; or
(c) reduction of fluid communication within the well.

16. A method of isolating, plugging or impairing a flow passage of a permeable zone of a subterranean formation during the recovery of oil or gas from the subterranean formation, the method comprising:
(a) introducing into the flow passage a pumpable well treatment fluid comprising a composite of a deformable core having coated thereon a viscosifying agent and a crosslinking agent, wherein the viscosifying agent is derivatized guar, underivatized guar or a combination thereof;
(b) increasing in-situ the viscosity of the well treatment composition by disassociating the viscosifying agent and crosslinking agent from the deformable core resulting in the formation of agglomerates of deformable core; and
(c) forming a fluid impermeable barrier in or across the flow passage from the agglomerates

wherein at least one of the following conditions prevail:
(i) the amount of crosslinking agent coated onto the deformable core is between from 0.001 to 2 percent based on the total weight of the deformable core, viscosifying agent and crosslinking agent; or
(ii) the amount of viscosifying agent coated onto the deformable core is between from about 0.1 to about 5 wt %, based on the total weight of deformable core and viscosifying agent.

17. The method of claim 16 , wherein the agglomerates of step (b) is a filter cake.

18. The method of claim 16 , wherein the deformable core is porous.

19. The method of claim 16 , wherein the well treatment fluid of step (a) is introduced into the well in the form of a loss circulation pill.

20. The method of claim 15 , wherein the deformable core has an apparent specific gravity less than or equal to 2.45.

21. The method of claim 15 , wherein the composite pumped into the well further comprises a crosslinking delaying agent coated onto the deformable core and further wherein the crosslinking delaying agent disassociates in-situ from the deformable core.

22. The method of claim 15 , wherein (i) the amount of crosslinking agent coated onto the deformable core is between from 0.001 to 2 percent based on the total weight of the deformable core, viscosifying agent and crosslinking agent; (ii) the amount of viscosifying agent coated onto the deformable

Assignees

• Brannon Harold Dean
• Hudson Harold Gene
• Bray Windal Scott
• Baker Hughes Inc

Inventors

• Brannon Harold Dean
• Hudson Harold Gene
• Bray Windal Scott

Classifications

• C09K8/516 Primary

  characterised by their form or by the form of their components, e.g. encapsulated material · CPC title