Infused and coated proppant containing chemical treatment agents and methods of using same

Patent metadata

Field	Value
Publication number	US-9951267-B2
Application number	US-201514857564-A
Country	US
Kind code	B2
Filing date	Sep 17, 2015
Priority date	Sep 17, 2014
Publication date	Apr 24, 2018
Grant date	Apr 24, 2018

Abstract

Proppant compositions and methods for using same are disclosed herein. In particular, a proppant composition for use in hydraulic fracturing is disclosed herein. The proppant composition can contain a plurality of particulates and at least one particulate of the plurality of particulates containing a chemical treatment agent. The at least one particulate having a long term permeability measured in accordance with ISO 13503-5 at 7,500 psi of at least about 10 D. The at least one chemical treatment agent can separate from the at least one particulate when located inside a fracture of a subterranean formation after a period of time.

First claim

What is claimed is:

1. A proppant composition for use in hydraulic fracturing, the composition comprising:
a plurality of particulates;
a non-degradable coating; and
at least one particulate of the plurality of particulates comprising a degradable shell encapsulating at least a portion of the non-degradable coating, and a chemical treatment agent, the at least one particulate having a long term permeability measured in accordance with ISO 13503-5 at 7,500 psi of at least about 10 D;
wherein the particulate is a porous particulate; and
wherein the at least one chemical treatment agent separates from the at least one particulate when located inside a fracture of a subterranean formation after a period of time.

2. The composition of claim 1 , further comprising a plurality of non-coated particulates.

3. The composition of claim 1 , wherein the chemical treatment agent comprises a scale inhibitor.

4. The composition of claim 3 , wherein the scale inhibitor comprises diethylenetriamine penta(methylene phosphonic acid).

5. The composition of claim 3 , wherein the scale inhibitor comprises one or more potassium salts of maleic acid copolymers.

6. The composition of claim 3 , wherein the at least one chemical treatment agent elutes from the plurality of particulates at a rate of less than 1 ppm/(gram*day) for at least about 2 hours after contacting the subterranean formation and at a rate of at least about 0.1 ppm/(gram*day) for at least 2 weeks after contacting an aqueous phase solution and/or a hydrocarbon phase solution.

7. The composition of claim 1 , wherein the non-degradable coating has a viscosity of about 1 cP to about 2,200 cP at a temperature of about 25° C.

8. The composition of claim 7 , wherein the non-degradable coating is a phenolic novolac resin.

9. The composition of claim 7 , wherein the chemical treatment agent is mixed with the non-degradable coating.

10. The composition of claim 8 , wherein the chemical treatment agent is mixed with the degradable shell.

11. The composition of claim 1 , wherein the degradable shell comprises one or more water-soluble polymers.

12. The composition of claim 1 , wherein the degradable shell is a thermoplastic material that degrades at temperatures of from about 25° C. to about 200° C. within a time period ranging from about 10 minutes to about 1,000 hours.

13. The composition of claim 1 , wherein the at least one chemical treatment agent elutes from the at least one particulate at a rate of less than 1 ppm/(gram*day) for at least about 2 hours after contacting the subterranean formation.

14. A method of hydraulic fracturing a subterranean formation, comprising:
injecting a hydraulic fluid into a subterranean formation at a rate and pressure sufficient to open a fracture therein; and
injecting a fluid containing the proppant composition of claim 1 into the fracture.

15. The method of claim 14 , wherein the non-degradable coating has a viscosity of about 1 cP to about 2,200 cP at a temperature of about 25° C.

16. The method of claim 15 , wherein the at least one chemical treatment agent elutes from the at least one particulate at a rate of less than 1 ppm/(gram*day) for at least about 2 hours after contacting the subterranean formation, and wherein the chemical treatment agent elutes from the at least one particulate in the fracture at a rate of at least about 0.1 ppm/(gram*day) for at least 2 weeks.

17. The composition of claim 1 , wherein the porous particulates have an internal interconnected porosity of about 5% to about 75%.

18. The composition of claim 1 , wherein the plurality of particulates have a bulk density of about 1.0 g/cc to about 2.1 g/cc.

19. The composition of claim 11 , wherein the water soluble polymers include sodium carboxymethyl cellulose, gum arabic, carrageenan gum, karaya gum, xanthan gum, carboxymethyl hydroxypropyl guar, cationic guar, dimethyl ammonium hydrolyzed collagen protein, poly (ethylene oxide), poly (propylene oxide), poly (ethylene oxide)-poly (propylene oxide) block copolymers, poly (1,4-oxybutylene) glycol, or poly (alkylene glycol diacrylates).

Assignees

• Carbo Ceramics Inc

Inventors

• Duenckel Robert
• Conner Mark
• Cannan Chad
• Roper Todd
• Leasure Joshua
• Lieng Thu
• Cady Daniel
• Read Peter A

Classifications

• E21B47/11

  using tracers; using radioactivity · CPC title

• C09K8/665

  containing inorganic compounds (proppants C09K8/80) · CPC title

• C09K8/64

  Oil-based compositions · CPC title

• C09K2208/26

  Gel breakers other than bacteria or enzymes · CPC title

• C09K8/805 Primary

  Coated proppants · CPC title