Degradable Material Assisted Diversion

• US 20080093073A1
• Filed: 10/16/2007
• Published: 04/24/2008
• Est. Priority Date: 10/24/2006
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Fredd, Christopher, Abad, Carlos, Chen, Yiyan, Bustos, Oscar, Adeogun, Goke
• Granted Patent: US 7,565,929 B2
• Time in Patent Office: Days
• US Class Current: 166/279
• CPC Class Codes: C09K 2208/30 Viscoelastic surfactants [VES]
• CPC Class Codes: C09K 8/68 containing organic compounds
• CPC Class Codes: C09K 8/74 combined with additives added for specific purposes
• CPC Class Codes: C09K 8/80 Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
• CPC Class Codes: C09K 8/88 macromolecular compounds
• CPC Class Codes: E21B 43/261 Separate steps of (1) cementing, plugging or consolidating and (2) fracturing or attacking the formation
• CPC Class Codes: E21B 43/267 reinforcing fractures by propping

Abstract

Degradable material assisted diversion (DMAD) methods for well treatment, DMAD treatment fluids, and removable plugs for DMAD in downhole operations. A slurry of solid degradable material is injected into the well, a plug of the degradable material is formed, a downhole operation is performed around the plug diverter, and the plug is then degraded for removal. Degradation triggers can be temperature or chemical reactants, with optional accelerators or retarders to provide the desired timing for plug removal. In multilayer formation DMAD fracturing, the plug isolates a completed fracture while additional layers are sequentially fractured and plugged, and then the plugs are removed for flowback from the fractured layers. In DMAD fluids, an aqueous slurry can have a solids phase including a degradable material and a fluid phase including a viscoelastic surfactant. The solids phase can be a mixture of fibers and a particulate material.

Claims

1. A method of well treatment, comprising:

a) injecting an aqueous slurry into a well penetrating a formation, wherein a solids phase of the slurry comprises an insoluble degradable material;

b) consolidating the degradable material to form a plug in a perforation, fracture, wellbore or combination thereof in the well;

c) performing a downhole operation in the well while the degradable material assists diversion from the plugged perforation, fracture, wellbore or combination thereof, wherein the downhole operation is selected from the group consisting of hydraulic fracturing, acidizing, well repair, installation of downhole equipment, and combinations thereof, and

d) degrading the consolidated degradable material to remove the plug and restore permeability to the perforation, fracture, wellbore or combination thereof.

2. The method of claim 1, wherein the degradable material comprises a polymer of monomer-derived units selected from the group consisting of esters, aromatic acids, amides and combinations thereof.

3. The method of claim 1, wherein the degradable material is selected from the group consisting of:

polymers and copolymers of lactide and glycolide;

polyethylene-terephthalate (PET);

polybutyleneterephthalate (PBT);

polyethylenenaphthalenate (PEN);

partially hydrolyzed polyvinyl acetate;

polyacrylamide, polymethacrylamide and derivatives thereof, and combinations and mixtures thereof.

4. The method of claim 1, wherein the degradable material is present in the slurry at a concentration of at least 4.8 g/L (40 lbm/1,000 gal).

5. The method of claim 1, wherein the consolidation comprises inducing a screenout of the solids phase.

6. The method of claim 1, wherein the solids phase includes fiber.

7. The method of claim 1 wherein the solids phase comprises a mixture of a fiber and a particulate material.

8. The method of claim 7, wherein the fiber comprises the degradable material and the particulate material comprises inert proppant.

9. The method of claim 7, wherein the fiber and the particulate material comprise the degradable material.

10. The method of claim 1 wherein the degradation is triggered by a temperature change, by chemical reaction between the degradable material and another reactant, or by a combination thereof.

11. The method of claim 1 wherein the degradation comprises dissolution of the degradable material.

12. The method of claim 1, wherein a fluid phase of the slurry comprises a viscoelastic surfactant, a co-surfactant, a rheology modifier, an aqueous brine, or a combination or mixture thereof.

13. A degradable material assisted diversion (DMAD) fracturing method, comprising the steps of:

a) injecting well treatment fluid into a well penetrating a multilayer formation to propagate a hydraulic fracture in a layer of the formation;

b) injecting an aqueous slurry comprising fibers of an insoluble, degradable material in a solids phase to form a plug of the consolidated fibers and isolate the hydraulic fracture from the wellbore, wherein the degradable material is present in the slurry at a concentration of at least 4.8 g/L (40 lbm/1,000 gal), and wherein a fluid phase of the slurry comprises a polymer viscosifier, a viscoelastic surfactant, a co-surfactant, a rheology modifier, a polymeric drag reducer, a surfactant drag reducer, a polymeric drag reduction enhancer, a monomeric drag reduction enhancer, an aqueous brine, or a combination or mixture thereof,

c) with the plug diverting from the previous hydraulic fracture, injecting well treatment fluid into the well to propagate a subsequent hydraulic fracture in another layer of the formation; and

d) thereafter degrading the degradable material to remove the plug.

14. The DMAD fracturing method of claim 13, further comprising sequentially repeating steps (b) and (c) one or a plurality of times for diversion from the previous hydraulic fractures and propagation of subsequent hydraulic fracture(s) in other layer(s), wherein the plugs are thereafter removed in step (d) by degrading the degradable material.

15. The DMAD fracturing method of claim 13, wherein a well treatment fluid passageway in the wellbore is maintained open between the formation layers for the subsequent hydraulic fracturing, wherein the previous fracture is isolated from the wellbore by the plug.

16. The DMAD fracturing method of claim 13, further comprising the step of perforation in advance of the fracture propagation in steps (a) and (c).

17. The DMAD fracturing method of claim 13, wherein the slurry injection comprises a tail stage of the hydraulic fracturing.

18. The DMAD fracturing method of claim 17, further comprising pumping one or more stages of proppant free aqueous fluid and one or more stages of proppant laden aqueous fluid.

19. The DMAD fracturing method of claim 18, where said aqueous fluid is a low viscosity slick water fluid selected from a polymeric friction reducing fluid, a surfactant based friction reducing fluid, or mixtures thereof.

20. The DMAD fracturing method of claim 13, wherein the removal of the plug is assisted by a wash.

21. The DMAD fracturing method of claim 13, comprising maintaining pressure in the wellbore adjacent the plug above the formation pressure of the isolated fracture.

22. The DMAD method of claim 13, wherein the fibers are present in the slurry at a concentration of at least 7.2 g/L (60 lbm/1,000 gal).

23. A well treatment fluid for degradable material assisted diversion (DMAD) treatment of a well, comprising an aqueous slurry comprising:

an insoluble degradable material in fiber form, wherein the degradable material comprises a polymer of monomer-derived units selected from the group consisting of esters, aromatic acids, amides and combinations thereof, and wherein the degradable material is present in the slurry at a concentration of at least 4.8 g/L (40 lbm/1,000 gal);

a particulate material; and

a fluid phase of the slurry comprising a viscoelastic surfactant, a co-surfactant, a rheology modifier, an aqueous brine, or a combination or mixture thereof.

24. The well treatment fluid of claim 23, wherein the fibers are selected from the group consisting of:

polymers and copolymers of lactide and glycolide;

polyethylene-terephthalate (PET);

polybutyleneterephthalate (PBT);

polyethylenenaphthalenate (PEN);

partially hydrolyzed polyvinyl acetate;

polyacrylamide, polymethacrylamide and derivatives thereof, and combinations and mixtures thereof.

25. The well treatment fluid of claim 23, wherein the particulate material comprises inert proppant having a distribution of sizes.