# US 10,767,101 B2 · Methods of controlling fines migration in a well > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 10,767,101 B2 - Document ID: US10767101B2 - Status: Granted - Kind: B2 - Application number: 16/021,142 - Filed: 2018-06-28 - Published: 2020-01-02 - Granted: 2020-09-08 - Earliest claimed: 2018-06-28 - Assignees: Baker Hughes, A Ge Company, LLC - Applicants: Anton Kovalchuk; Ramon Garza - Inventors: Anton Kovalchuk; Ramon Garza - Web page: https://patentgrep.com/patent/US10767101B2 ## CPC - C09K 8/5751: {Macromolecular compounds (C09K8/5756 takes precedence)} - C09K 8/516: characterised by their form or by the form of their components, e.g. encapsulated material - C09K 8/68: containing organic compounds - C09K 8/70: characterised by their form or by the form of their components, e.g. foams - C09K 8/74: combined with additives added for specific purposes - C09K 8/80: Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open - C09K 8/805: {Coated proppants} - E21B 43/04: Gravelling of wells - E21B 43/20: Displacing by water - E21B 43/26: by forming crevices or fractures - E21B 43/267: reinforcing fractures by propping - C09K: MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS ## 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. ## Claims ### Claim 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. ### Claim 2 (depends on 1) The method of claim 1, wherein the polymeric core is a recycled rubber in a particulate form. ### Claim 3 (depends on 2) The method of claim 2, wherein the recycled rubber as a size of about 3.5 to about 40 mesh. ### Claim 4 (depends on 1) 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. ### Claim 5 (depends on 4) The method of claim 4, wherein the curable thermoset coating further comprises a curing agent. ### Claim 6 (depends on 5) 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. ### Claim 7 (depends on 1) 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. ### Claim 8 (depends on 1) The method of claim 1, wherein the treatment fluid further comprises a proppant. ### Claim 9 (depends on 8) The method of claim 8, wherein the proppant comprises an uncoated proppant, a coated proppant, or a combination thereof. ### Claim 10 (depends on 8) 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. ### Claim 11 (depends on 1) The method of claim 1, wherein the forming the fluid-permeable pack comprises consolidating the coated polymeric particles with the coating during curing. ### Claim 12 (depends on 1) 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. ### Claim 13 (depends on 12) The method of claim 12, wherein introducing the treatment fluid and the performing the downhole operation occur simultaneously. ### Claim 14 (depends on 12) The method of claim 12, wherein performing the downhole operation precedes introducing the treatment fluid. ### Claim 15 (depends on 1) 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. ### Claim 16 (depends on 1) The method of claim 1, wherein the fluid-permeable pack is disposed adjacent the subterranean formation. ### Claim 17 (depends on 1) The method of claim 1, wherein the fluid-permeable pack is disposed in a fracture created by a hydraulic fracturing operation. ### Claim 18 (depends on 1) The method of claim 1, further comprising installing a screen device in the wellbore. ### Claim 19 (depends on 18) 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.