# US 12,110,447 B1 · Drilling fluid composition and method for removing hydrogen sulfide content using the same

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- Number: US 12,110,447 B1
- Document ID: US12110447B1
- Status: Granted
- Kind: B1
- Application number: 18/297,041
- Filed: 2023-04-07
- Published: 2024-10-10
- Granted: 2024-10-08
- Earliest claimed: 2023-04-07
- Assignees: King Fahd University of Petroleum and Minerals
- Applicants: King Fahd University of Petroleum and Minerals
- Inventors: Ashraf Ahmed; Salaheldin Elkatatny; Sagheer Onaizi
- Web page: https://patentgrep.com/patent/US12110447B1

## CPC

- C09K 8/032: {Inorganic additives}
- C09K 8/5045: {containing inorganic compounds}
- E21B 41/02: in situ inhibition of corrosion in boreholes or wells
- C09K 2208/18: Bridging agents, i.e. particles for temporarily filling the pores of a formation; Graded salts
- C09K 2208/20: Hydrogen sulfide elimination
- E21B 21/067: {Separating gases from drilling fluids}
- 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 drilling fluid composition includes a base fluid; at least one additive selected from the group consisting of an anti-foaming agent, a fluid-loss additive, a viscosity modifier, a shale stabilizer, an alkali compound, a bridging agent, and a weighting agent; and 0.01 to 0.5 weight percentage (wt. %) of particles of steel slag, based on a total weight of the drilling fluid composition. A method for reducing a hydrogen sulfide (H2S) content of a H2S-containing subterranean formation. A process for removing H2S from a H2S-containing gas composition by the drilling fluid composition.

## Claims

### Claim 1

A drilling fluid composition, comprising:
an aqueous base fluid;
at least one additive selected from the group consisting of an anti-foaming agent, a fluid-loss additive, a viscosity modifier, a shale stabilizer, an alkali compound, a bridging agent, and a weighting agent;
0.01 to 0.5 wt. % of particles of steel slag, based on a total weight of the drilling fluid composition; and
iron gluconate particles having an average particle size (D50) in a range of 10 to 60 μm;
wherein the steel slag comprises 30 to 60 wt. % ZnO, 20 to 50 wt. % Na2O, 5 to 25 wt. % Cl, and 0.5 to 6 wt. % Fe2O3, each wt. % based on a total weight of the steel slag as determined by X-ray fluorescence (XRF); and
wherein the steel slag particles have an irregular shape, and an average particle size (D50) in a range of 5 to 20 μm.

### Claim 2 (depends on 1)

The drilling fluid composition of claim 1, wherein the steel slag has an average particle size (D50) of 11 to 13 μm.

### Claim 3

A drilling fluid composition, comprising:
an aqueous base fluid;
at least one additive selected from the group consisting of an anti-foaming agent, a fluid-loss additive, a viscosity modifier, a shale stabilizer, an alkali compound, a bridging agent, and a weighting agent;
0.01 to 0.5 wt. % of particles of steel slag, based on a total weight of the drilling fluid composition, wherein the steel slag particles have an irregular shape, and an average particle size (D50) in a range of 5 to 20 μm;
0.01 to 0.1 wt. % of the anti-foaming agent selected from the group consisting of polydimethylsiloxane, fatty acid ester, silicon dioxide, and vegetable oil;
0.01 to 0.5 wt. % of the viscosity modifier selected from the group consisting of a clay, a saccharide, a polysaccharide, a cellulose, an acrylate polymer and copolymer, and a polyvinyl polymer and copolymer;
0.5 to 5 wt. % of the fluid-loss additive selected from the group consisting of a starch, a starch derivative, a cellulose, and a cellulose derivative;
5 to 20 wt. % of the shale stabilizer selected from the group consisting of a sodium salt, and a sulfonated asphalt;
0.01 to 0.5 wt. % of the alkali compound selected from the group consisting of caustic soda and soda ash;
1 to 10 wt. % of the bridging agent selected from the group consisting of sodium borate, boric oxide, calcium carbonate, and magnesium oxide;
20 to 40 wt. % of the weighting agent selected from the group consisting of barite and hematite; and
45 to 65 wt. % of the base fluid, each wt. % based on a total weight of the drilling fluid composition.