# US 10,370,951 B2 · Squeeze treatment for in situ scavenging of hydrogen sulfide > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 10,370,951 B2 - Document ID: US10370951B2 - Status: Granted - Kind: B2 - Application number: 15/899,017 - Filed: 2018-02-19 - Published: 2018-06-21 - Granted: 2019-08-06 - Earliest claimed: 2012-12-19 - Assignees: Ecolab USA Inc. - Applicants: Ecolab USA Inc. - Inventors: Joseph Paul Bailey; Aaron D. Martinez; Erick J. Acosta; Ravindranath Mukkamala; Maximilian A. Silvestri; Jose M. Macias - Web page: https://patentgrep.com/patent/US10370951B2 ## CPC - C09K 8/532: Sulfur - C09K 8/528: inorganic depositions, e.g. sulfates or carbonates - C09K 8/54: Compositions for in situ inhibition of corrosion in boreholes or wells - E21B 43/25: Methods for stimulating production {(by vibrating earth formations E21B43/003)} - C09K 2208/20: Hydrogen sulfide elimination - 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 performing a squeeze treatment comprises pumping a treatment fluid under pressure through a wellbore into a subterranean formation, wherein the treatment fluid includes a hydrogen sulfide scavenging compound that adsorbs onto the subterranean formation in a region around the wellbore. Production fluids are then allowed to flow from the subterranean formation into the wellbore, wherein the production fluids contact the adsorbed hydrogen sulfide scavenging compound as the production fluids flow through the region around the wellbore, and wherein the production fluids contain hydrogen sulfide that reacts with the hydrogen sulfide scavenging compound to reduce an amount of hydrogen sulfide in the production fluids before the production fluids flow into the wellbore. ## Claims ### Claim 1 A squeeze treatment method for reducing the amount of hydrogen sulfide in a hydrocarbon-containing fluid, comprising: pumping a treatment fluid under pressure through a wellbore into a subterranean formation and maintaining the treatment fluid in the region around the wellbore for a predetermined period of time, wherein the treatment fluid includes a hydrogen sulfide scavenging compound that adsorbs onto the subterranean formation in a region around the wellbore; flowing production fluids from the subterranean formation into the wellbore, wherein the production fluids contact the adsorbed hydrogen sulfide scavenging compound as the production fluids flow through the region around the wellbore, and wherein the production fluids contain hydrogen sulfide that reacts with the hydrogen sulfide scavenging compound to reduce an amount of hydrogen sulfide in the production fluids before the production fluids flow into the wellbore, monitoring the concentration of hydrogen sulfide in the production fluids flowing from the subterranean formation through the wellbore; and in response to the concentration of hydrogen sulfide exceeding a threshold concentration, stopping the flow of production fluids from the subterranean formation into the wellbore, then pumping an additional amount of the treatment fluid under pressure through the wellbore into the subterranean formation, then maintaining the treatment fluid in the region around the wellbore for a predetermined period of time, and then restarting the flow of production fluids from the subterranean formation into the wellbore, wherein the hydrogen sulfide scavenging compound is an alpha-hydroxy alkyl ester functionalized with a phosphate group, phosphonate group, sulfate group, sulfonate group, or hydroxyl group; or an alpha-hydroxy alkyl ether functionalized with a phosphate group, phosphonate group, sulfate group, sulfonate group, or hydroxyl group. ### Claim 2 (depends on 1) The method of claim 1, wherein the predetermined period of time is between 12 and 16 hours. ### Claim 3 (depends on 1) The method of claim 1, wherein the predetermined period of time is greater than 16 hours. ### Claim 4 (depends on 1) The method of claim 1, wherein the hydrogen sulfide scavenging compound is functionalized with at least one functional group selected from a phosphate group, phosphonate group, sulfonate group and a sulfate group. ### Claim 5 (depends on 1) The method of claim 1, wherein the hydrogen sulfide scavenging compound is functionalized with two phosphate groups or two sulfate groups. ### Claim 6 (depends on 1) The method of claim 1, wherein the hydrogen sulfide scavenging compound is functionalized with two phosphonate groups or two sulfonate groups. ### Claim 7 (depends on 1) The method of claim 1, wherein the hydrogen sulfide scavenging compound is functionalized with at least two hydroxyl groups. ### Claim 8 (depends on 1) The method of claim 1, wherein the hydrogen sulfide scavenging compound is amine-free. ### Claim 9 (depends on 1) The method of claim 1, wherein the treatment fluid includes between 5 and 20 volume percent of the hydrogen sulfide scavenging compound. ### Claim 10 (depends on 1) The method of claim 1, wherein the treatment fluid includes between 10 and 15 volume percent of the hydrogen sulfide scavenging compound. ### Claim 11 (depends on 1) The method of claim 1, wherein the treatment fluid includes a mixture of water and ethanol. ### Claim 12 (depends on 1) The method of claim 1, wherein the treatment fluid includes a component selected from scale inhibitors, asphaltene inhibitors, biocides, and combinations thereof. ### Claim 13 (depends on 1) The method of claim 1, wherein the ratio of hydrogen sulfide scavenging compound to hydrogen sulfide is about 12:1 in the production fluid.