# US 2021/0340432 A1 · Methods of Using Delayed Release Well Treatment Composititions > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 2021/0340432 A1 - Document ID: US20210340432A1 - Status: Published application - Kind: A1 - Application number: 16/973,714 - Filed: 2019-07-30 - Published: 2021-11-04 - Earliest claimed: 2018-07-30 - Assignees: Baker Hughes Holdings LLC - Applicants: Baker Hughes Holdings LLC - Inventors: Sumit Bhaduri; D.V. Satyanarayana Gupta; Shawn Shipman - Web page: https://patentgrep.com/patent/US20210340432A1 ## CPC - C09K 8/70: characterised by their form or by the form of their components, e.g. foams - C09K 8/03: Specific additives for general use in well-drilling compositions - C09K 8/536: characterised by their form or by the form of their components, e.g. encapsulated material - C09K 8/58: Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids - C09K 8/62: Compositions for forming crevices or fractures - E21B 43/267: reinforcing fractures by propping - E21B 47/11: using tracers; using radioactivity - C09K 8/524: organic depositions, e.g. paraffins or asphaltenes - C09K 2208/20: Hydrogen sulfide elimination - C09K 2208/22: Hydrates inhibition by using well treatment fluids containing inhibitors of hydrate formers - C09K 2208/32: Anticorrosion additives - 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 composite for controlling the release of a well treatment agent or for inhibiting or preventing the formation of contaminants into a fluid or a surface within a reservoir contains a well treatment agent adsorbed onto a water-insoluble or oil-insoluble adsorbent, the adsorbent having a surface area between from about 110 m2/g to about 700 m2/g. The composite may be also used to monitor the production of fluids from the reservoir or the flow of fluids in the reservoir. ## Claims ### Claim 1 A method of controlling the release of a well treatment agent into a well or onto the surface of a subterranean formation penetrated a well, the method comprising pumping into the well a composite comprising the well treatment agent adsorbed onto a water-insoluble adsorbent wherein the well treatment agent inhibits or controls the formation of contaminants within the well by slowly releasing the well treatment agent into the well, wherein the surface area of the adsorbent is between from about 110 m2/g to about 700 m2/g. ### Claim 2 (depends on 1) The method of claim 1, wherein the release of the well treatment agent is controlled during a stimulation or sand control operation. ### Claim 3 (depends on 2) The method of claim 2, wherein the stimulation operation is hydraulic fracturing or acidizing. ### Claim 4 (depends on 2) The method of claim 2, wherein the stimulation operation is slickwater fracturing. ### Claim 5 (depends on 3) The method of claim 3, wherein the particle size of the composite during hydraulic fracturing is less than the transverse dimension of a dendritic fracture extending from a primary fracture. ### Claim 6 (depends on 3) The method of claim 3, wherein the rate of release of the hydrocarbon soluble, water soluble or both hydrocarbon and water soluble well treatment agent is controlled into a dendritic fracture extending from a primary fracture and further wherein a fluid containing the composite is pumped into near field primary fractures and far field secondary fractures propped open with a proppant having a particle size less than or equal to 150 μm and wherein the particle size of the composite is less than or equal to the particle size of the proppant. ### Claim 7 A method of fracturing multiple subterranean zones surrounded by a wellbore which comprises: (a) pumping into each zone to be fractured a fracturing fluid, wherein the fracturing fluid pumped into each zone comprises a composite comprising a hydrocarbon soluble, water soluble or both hydrocarbon and water soluble tracer adsorbed onto a water-insoluble adsorbent, wherein the surface area of the adsorbent is between from about 110 m2/g to about 700 m2/g and further wherein the tracer introduced into each zone is qualitatively and quantitatively distinguishable; (b) solubilizing the tracer into fluids produced from the zone into which the composite comprising the composite is pumped; and (c) identifying the zone within the subterranean formation from which the recovered fluid was produced by identifying the tracer in the recovered fluid. ### Claim 8 (depends on 7) The method of claim 7, further wherein: (i) the fracturing fluid pumped into each of the multiple productive zones contains a different pre-determined tracer adsorbed onto the water-insoluble and oil-insoluble adsorbent and further wherein fluids produced from each of the multiple productive zones is quantitatively detectable by the pre-determined tracer adsorbed onto the water-insoluble and oil-insoluble adsorbent in the fracturing fluid; (ii) the amount of the solubilized tracers in hydrocarbons produced from the well is quantitatively determined; and (iii) the amount of hydrocarbons produced from the multiple productive zones is determined from the solubilized tracers. ### Claim 9 A method of increasing hydrocarbon production from a production well penetrating a hydrocarbon-bearing reservoir, wherein more than one injection well is associated with the production well, the method comprising: (a) injecting into the more than one injection well an aqueous fluid having a hydrocarbon soluble, water soluble or both hydrocarbon and water soluble tracer adsorbed onto a water-insoluble and oil-insoluble adsorbent, wherein the surface area of the adsorbent is between from about 110 m2/g to about 700 m2/g and maintaining pressure in the hydrocarbon-bearing reservoir; (b) identifying from hydrocarbons recovered from the production well, upon water breakthrough in the production well, the injection well into which the breakthrough water was injected by qualitatively determining the presence of the tracer in the recovered hydrocarbons; and (c) shutting off the injection well identified in step (b). ### Claim 10 (depends on 9) The method of claim 9, wherein pressure in the hydrocarbon-bearing reservoir is maintained above the bubble point of the hydrocarbons in the reservoir. ### Claim 11 (depends on 1, 2, 3, 4, 5, 6, 7, 8, 9, 10) The method of any of claims 1 to 10, wherein at least one of the following is true: (a) the weight ratio of the well treatment agent to adsorbent in the composite is between from about 9:1 to about 1:9. (b) the lifetime of the composite after being introduced into the well is at least nine months; (c) the well treatment agent is selected from the group consisting of scale inhibitors, corrosion inhibitors, paraffin inhibitors, salt inhibitors, gas hydrate inhibitors, asphaltene inhibitors, oxygen scavengers, biocides, foaming agent, emulsion breakers, surfactants, hydrogen sulfide scavengers, water soluble tracers, oil soluble tracers and mixtures thereof; (d) the amount of the well treatment agent in the composite is between from about 0.05 to about 25 weight percent; (e) the water-insoluble adsorbent is selected from the group consisting of activated carbon, silica particulate, precipitated silica, zeolite, diatomaceous earth, ground walnut shells, fuller's earth, alumina and organic synthetic high molecular weight water-insoluble adsorbents; (f) the composite is pumped into the well in a fluid further wherein the amount of composite in the fluid is between from about 15 ppm to about 100,000 ppm; or (g) the particle size of the composite is less than 100 μm. ### Claim 12 (depends on 11) The method of claim 11, wherein one of the following is true: (a) the adsorbent is diatomaceous earth or precipitated silica; or (b) the well treatment agent is a scale inhibitor. ### Claim 13 (depends on 1, 2, 3, 4, 5, 6, 7, 8, 9, 10) The method of any of claims 1 to 10, wherein at least a portion of the surface of the composite is coated with a release resistant layer. ### Claim 14 (depends on 13) The method of claim 13, wherein the release resistant layer is selected from the group consisting of phenol formaldehyde resins, melamine formaldehyde resins, urethane resins, epoxy resins, polyamides, polyethylene, polystyrene, furan resins and mixtures thereof. ### Claim 15 (depends on 1, 2, 3, 4, 5, 6, 7, 8, 9, 10) The method of any of claims 1 to 10, wherein the composite and a binder are formed into a shaped compressed pellet and wherein the shaped compressed pellet is pumped into the well.