# US 12,110,455 B2 · Carbon dioxide sequestered proppants for well stimulation

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- Number: US 12,110,455 B2
- Document ID: US12110455B2
- Status: Granted
- Kind: B2
- Application number: 18/065,345
- Filed: 2022-12-13
- Published: 2023-06-15
- Granted: 2024-10-08
- Earliest claimed: 2021-12-13
- Assignees: Chevron U.S.A. Inc.
- Applicants: Chevron U.S.A. Inc.
- Inventors: Caleb Kimbrell Carroll; Seung Jin Han; Said Rachid Daher
- Web page: https://patentgrep.com/patent/US12110455B2

## CPC

- C09K 8/805: {Coated proppants}
- C09K 8/62: Compositions for forming crevices or fractures
- C09K: MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE

## Abstract

A method of making a hydraulic fracturing slurry can include contacting an aqueous solution comprising calcium ions with a carbon dioxide source producing a carbonated aqueous solution. Substrate particles can be submerged in the carbonated aqueous solution to produce a calcium carbonate coated proppant wherein the carbon dioxide is sequestered in the calcium carbonate. The calcium coated proppant can be combined with hydraulic fracturing fluid to produce a hydraulic fracturing slurry. Alternatively, the calcium carbonate coated proppant can be combined with silica sand to produce a proppant composition used in a hydraulic fracturing slurry.

## Claims

### Claim 1

A method of stimulating a well comprising injecting a hydraulic fracturing slurry into the well, the hydraulic fracturing slurry comprising:
hydraulic fracturing fluid; and
a proppant composition comprising 50% or more by weight of silica sand particles and up to 50% by weight of calcium carbonate coated particles having a diameter in a range of 140 mesh to 70 mesh, the calcium carbonate coated particles comprising a substrate, the substrate having a hardness less than silica sand, and a coating of calcium carbonate comprising sequestered carbon dioxide, whereby the diameter of the calcium carbonate coated particles and the hardness of the substrate cause the proppant composition to be concentrated at one end of fractures in the well.

### Claim 2 (depends on 1)

The method of claim 1, wherein the calcium carbonate coated particles are further coated with a protective coating.

### Claim 3 (depends on 1)

The method of claim 1, wherein the calcium carbonate coated particles consist of calcium carbonate coated with a protective coating.

### Claim 4 (depends on 1)

The method of claim 1, wherein the calcium carbonate coated particles have a mesh size of 140 mesh.

### Claim 5 (depends on 1)

The method of claim 1, wherein the substrate particles have a mesh size range between 100 mesh and 200 mesh and the calcium carbonate coated particles have a mesh size range between 70 mesh and 140 mesh.

### Claim 6 (depends on 5)

The method of claim 5, wherein the substrate particles are drilling cuttings from well drilling.

### Claim 7 (depends on 6)

The method of claim 6, wherein the calcium carbonate coated particles are formed by submerging the drilling cuttings in a carbonated aqueous solution, the carbonated aqueous solution formed by contacting an aqueous solution comprising calcium ions with a carbon dioxide source.

### Claim 8 (depends on 3)

The method of claim 3, wherein the sequestered carbon dioxide calcium carbonate coated particles in combination with the protective coating have a mesh size range between 70 mesh and 140 mesh.