Methods of controlling fines migration in a well

Patent metadata

Field	Value
Publication number	US-10767101-B2
Application number	US-201816021142-A
Country	US
Kind code	B2
Filing date	Jun 28, 2018
Priority date	Jun 28, 2018
Publication date	Sep 8, 2020
Grant date	Sep 8, 2020

Abstract

A method of treating a subterranean formation penetrated by a wellbore comprises: introducing into the subterranean formation a treatment fluid comprising coated polymeric particles having a polymeric core and a curable thermoset coating disposed on the polymeric core; allowing the curable thermoset coating to cure under downhole conditions; and forming a fluid-permeable pack from the coated polymeric particles, the fluid-permeable pack reducing or substantially preventing the passage of formation particles from the subterranean formation into the wellbore while allowing passage of formation fluids from the subterranean formation into the wellbore.

First claim

What is claimed is:

1. A method of treating a subterranean formation penetrated by a wellbore, the method comprising:
introducing into the subterranean formation a treatment fluid comprising coated polymeric particles having a polymeric core and a curable thermoset coating disposed on the polymeric core, the polymeric core comprising a rubber, the rubber comprising a nitrile rubber (NBR), a hydrogenated nitrile rubber (HNBR), a styrene-butadiene rubber (SBR), an ethylene propylene diene monomer rubber (EPDM), a natural rubber, a silicone rubber, a polybutadiene, polyisoprene, butyl rubber, or a combination comprising at least one of the foregoing, the curable thermoset coating having a thickness of about 10 μm to about 50 μm, and the coated polymeric particles having a true specific gravity of about 0.5 g/cc to about 1.5 g/cc;
allowing the curable thermoset coating to cure under downhole conditions;
forming a fluid-permeable pack from the coated polymeric particles;
flowing a formation fluid through the fluid-permeable pack from the subterranean formation into the wellbore; and
reducing or substantially preventing the passage of formation particles from the subterranean formation into the wellbore.

2. The method of claim 1 , wherein the polymeric core is a recycled rubber in a particulate form.

3. The method of claim 2 , wherein the recycled rubber as a size of about 3.5 to about 40 mesh.

4. The method of claim 1 , wherein the curable thermoset coating comprises an uncured or partially cured thermoset including an epoxy resin, a phenolic resin, a vinyl ester resin, a furan resin, a polyurethane, a polyester, a cyanate ester, a polyimide, a bismaleimide, a liquid rubber or a combination comprising at least one of the foregoing.

5. The method of claim 4 , wherein the curable thermoset coating further comprises a curing agent.

6. The method of claim 5 , wherein the curing agent comprises an amine, an oxygen-containing compound, elemental sulfur, a sulfur-containing compound, a peroxide, a Lewis acid, a Lewis base; or a combination comprising at least one of the foregoing.

7. The method of claim 1 , wherein the coated polymeric particles have an average particle size of about 1,000 μm to about 7,000 μm.

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

9. The method of claim 8 , wherein the proppant comprises an uncoated proppant, a coated proppant, or a combination thereof.

10. The method of claim 8 , wherein the weight ratio of the coated polymeric particles relative to the proppant is about 10:90 to about 90:10.

11. The method of claim 1 , wherein the forming the fluid-permeable pack comprises consolidating the coated polymeric particles with the coating during curing.

12. The method of claim 1 , further comprising performing a downhole operation comprising one or more of the following: a hydraulic fracturing operation; an acidizing treatment; a gravel packing operation; or a flooding operation.

13. The method of claim 12 , wherein introducing the treatment fluid and the performing the downhole operation occur simultaneously.

14. The method of claim 12 , wherein performing the downhole operation precedes introducing the treatment fluid.

15. The method of claim 1 , further comprising adjusting the permeability of the fluid-permeable pack by changing the size of the coated polymeric particles, the thickness of the curable thermoset coating, a composition of the curable thermoset coating, or a combination thereof.

16. The method of claim 1 , wherein the fluid-permeable pack is disposed adjacent the subterranean formation.

17. The method of claim 1 , wherein the fluid-permeable pack is disposed in a fracture created by a hydraulic fracturing operation.

18. The method of claim 1 , further comprising installing a screen device in the wellbore.

19. The method of claim 18 , wherein the fluid-permeable pack is disposed in an annular area between the exterior of the screen device and the interior of the wellbore.

Assignees

• Kovalchuk Anton
• Garza Ramon
• Baker Hughes A Ge Co Llc

Inventors

• Kovalchuk Anton
• Garza Ramon

Classifications

• E21B43/26

  by forming crevices or fractures · CPC title

• E21B43/267

  reinforcing fractures by propping · CPC title

• E21B43/04

  Gravelling of wells · CPC title

• C09K8/805

  Coated proppants · CPC title

• C09K8/74

  combined with additives added for specific purposes · CPC title