Method of using composite diversion particle agglomerations

Patent metadata

Field	Value
Publication number	US-11787994-B2
Application number	US-202217676202-A
Country	US
Kind code	B2
Filing date	Feb 20, 2022
Priority date	Aug 22, 2018
Publication date	Oct 17, 2023
Grant date	Oct 17, 2023

Abstract

The present disclosure relates to material for use in oil and gas well completion activities. More particularly, the present disclosure relates to diversion particles, along with methods for making and using the diversion particles. In an embodiment, a composite diversion material includes a non-degradable component comprising two or more non-degradable particulates, wherein the non-degradable particulates have a long term permeability at 7,500 psi of at least about 20 D. The composite diversion material includes a degradable component surrounding at least a portion of the non-degradable component. In another embodiment, a method of making a composite diversion material includes mixing non-degradable proppant particles with an aqueous solution containing a first degradable material to provide a mixture having a proppant concentration of at least about 20 volume percent. The method includes drying the mixture at a temperature of from about 25° C. to about 200° C. to provide the composite diversion material.

First claim

What is claimed is:

1. A method of placing a diverter material in a subterranean formation, comprising:
injecting a hydraulic fluid comprising a composite diversion material into a wellbore and, subsequently into an adjacent subterranean formation at a rate and pressure sufficient to place the composite diversion material into a fracture in the subterranean formation; and
removing a degradable component from the composite diversion material by contact with a water-based fluid after a period of time from placement in the fracture,
wherein the composite diversion material comprises:
an agglomeration of a non-degradable component and the degradable component, wherein:
the non-degradable component comprises three or more non-degradable particulates, wherein the non-degradable particulates have a long term permeability at 7,500 psi of at least about 20 D; and
the degradable component is coated onto and encapsulates two or more non-degradable particulates;

wherein the degradable component comprises a tracer material.

2. The method of claim 1 , wherein one of the degradable component or the non-degradable component comprises a thermal neutron absorbing material.

3. The method of claim 1 , further comprising:
obtaining a first data set by:
lowering into the wellbore a pulsed neutron logging tool comprising a pulsed neutron source and a detector,
emitting pulses of neutrons from the pulsed neutron source into the fracture containing the composite diversion material,
detecting capture gamma rays;

obtaining a second data set by:
lowering into the wellbore a pulsed neutron logging tool comprising a pulsed neutron source and a detector,
emitting pulses of neutrons from the pulsed neutron source into the fracture containing the composite diversion material,
detecting capture gamma rays; and

comparing the first data set and the second data set to determine removal of the degradable component from the composite diversion material placed in the fracture.

4. The method of claim 1 , where in the fracture experiences a reduction in width of less than 5% when the degradable component is substantially or completely removed from the composite diversion material from the composite diversion material was initially placed into the fracture.

5. The method of claim 1 , wherein the degradable component further comprises one or more of polylactic acid, polyglycolic acid, starch, cellulose, carboxymethyl cellulose, acrylic latex, guar, polytrimethylene terephthalate, polybutylene succinate, polybutylene adipate terephthalate, polybutylene adipate succinate, polyolefins, water-soluble polymers and any combinations thereof.

6. The method of claim 1 , wherein the non-degradable component encapsulates about 4 to about 5 non-degradable particulates.

7. The method of claim 1 , wherein the degradable component comprises a polymeric material configured to degrade in the presence of a water-based fluid at a temperature from about 25° C. to about 180° C.

8. The method of claim 7 , wherein the water-based fluid is brine.

9. The method of claim 1 , wherein the degradable component comprises a functionalized or hydrolyzed polyvinyl alcohol.

10. The method of claim 9 , wherein the degradable component is partially functionalized.

11. The method of claim 9 , wherein the degradable component is fully functionalized.

12. The method of claim 9 , wherein the degradable component is functionalized by reacting a polyvinyl alcohol with acetic acid.

13. The method of claim 12 , wherein the degradable component is polyvinyl acetate.

14. The method of claim 1 , wherein the non-degradable component encapsulates about 3 to about 6 non-degradable particulates.

15. The method of claim 1 , wherein the degradable component encapsulates 2 to 25 non-degradable particles.

16. The method of claim 15 , wherein the degradable component encapsulates 2 to 5 non-degradable particles.

17. The method of claim 15 , wherein the non-degradable particles are in direct contact with each other.

18. The method of claim 15 , wherein the degradable component encapsulates 5 to 25 non-degradable particles.

19. The method of claim 18 , wherein the degradable component encapsulates 7 to 15 non-degradable particles.

Assignees

• Carbo Ceramics Inc

Inventors

• Lieng Thu
• Roper Todd
• Orekha Olatunji

Classifications

• C09K8/516 Primary

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

• C09K8/5045

  containing inorganic compounds · CPC title

• C09K8/5083

  obtained by reactions only involving carbon-to-carbon unsaturated bonds · CPC title

• C09K8/805 Primary

  Coated proppants · CPC title

• C09K8/845

  containing inorganic compounds · CPC title