# US 2014/0190694 A1 · Method of Treating Ultra-Low Permeable Subterranean Formations Using Proppant Particulates Coated with Degradable Material > Agents: this data is available as JSON from the patentgrep API and MCP server — see https://patentgrep.com/llms.txt - Number: US 2014/0190694 A1 - Document ID: US20140190694A1 - Status: Published application - Kind: A1 - Application number: 13/734,429 - Filed: 2013-01-04 - Published: 2014-07-10 - Earliest claimed: 2013-01-04 - Assignees: Halliburton Energy Services, Inc. - Applicants: Halliburton Energy Services, Inc. - Inventors: Feng Liang; Bradley L. Todd; Thomas D. Welton - Web page: https://patentgrep.com/patent/US20140190694A1 ## CPC - E21B 43/267: reinforcing fractures by propping - C09K 8/805: {Coated proppants} - E21B: EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS - C09K: MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE ## Abstract Methods of treating an ultra-low permeability subterranean formation having a fracture complexity comprising interconnected fractures including providing a fracturing fluid comprising a base fluid and coated proppant, wherein the coated proppant comprise proppant coated with a degradable material; introducing the fracturing fluid into the ultra-low permeability subterranean formation at a rate and pressure above a fracture gradient of the ultra-low permeability subterranean formation; placing the coated proppant into a fracture of the interconnected fractures so as to form a temporarily impermeable proppant pack comprising the coated proppant therein and reduce or prevent the extension of the fracture; reducing the pressure below the fracture gradient; and degrading the degradable material coated onto the coated proppant so as to cause the temporarily impermeable proppant pack to become a permeable proppant pack. ## Claims ### Claim 1 A method of treating an ultra-low permeability subterranean formation having a fracture complexity comprising interconnected fractures comprising: providing a fracturing fluid comprising a base fluid and coated proppant, wherein the coated proppant comprise proppant coated with a degradable material; introducing the fracturing fluid into the ultra-low permeability subterranean formation at a rate and pressure above a fracture gradient of the ultra-low permeability subterranean formation; placing the coated proppant into at least one fracture of the interconnected fractures so as to form a temporarily impermeable proppant pack comprising the coated proppant therein and reduce or prevent the extension of the at least one fracture; reducing the pressure below the fracture gradient; and degrading the degradable material coating the coated proppant so as to cause the temporarily impermeable proppant pack to become a permeable proppant pack. ### Claim 2 (depends on 1) The method of claim 1 wherein the temporarily impermeable proppant pack is capable of reducing flow by at least 75% at a differential pressure of at least about 100 psi. ### Claim 3 (depends on 1) The method of claim 1 wherein the permeable proppant pack is capable of allowing at least 75% flow at a differential pressure of at least about 500 psi. ### Claim 4 (depends on 1) The method of claim 1 wherein the treatment fluid further comprises a consolidating agent. ### Claim 5 (depends on 1) The method of claim 1 wherein the degradable material is selected from the group consisting of a poly(hydroxyl alkanoate); a poly(alpha-hydroxy) acid; a poly(beta-hydroxy alkanoate); a poly(omega-hydroxy alkanoate); a poly(alkylene dicarboxylate; a polyanhydride; a poly(orthoester); a polycarbonate; an aliphatic polyester; a poly(lactide); a poly(glycolide); a poly(hydroxybutyrate); a poly(anhydride); an aliphatic polycarbonate; a poly(amino acid); a poly(ethylene oxide); a polyphosphazene; any derivatives thereof; and any combinations thereof. ### Claim 6 (depends on 1) The method of claim 1 wherein the degradable material further comprises a plasticizer selected from the group consisting of polyethylene glycol; polyethylene oxide; oligomeric lactic acid; a citrate ester; a glucose monoester; a partially fatty acid ester; polyethylene glycol monolaurate; triacetin; poly(e-caprolactone); poly(hydroxybutyrate); glycerin-l-benzoate-2,3-dilaurate; glycerin-2-benzoate-l,3-dilaurate; bis(butyl diethylene glycol)adipate; ethylphthalylethyl glycolate; glycerin diacetate monocaprylate; diacetyl monoacyl glycerol; polypropylene glycol; poly(propylene glycol)dibenzoate; dipropylene glycol dibenzoate; glycerol; ethyl phthalyl ethyl glycolate; poly(ethylene adipate)distearate; di-iso-butyl adipate; any derivatives thereof; and combinations thereof. ### Claim 7 A method of treating an ultra-low permeability subterranean formation having a fracture complexity comprising interconnected fractures comprising: providing a fracturing fluid comprising a base fluid, coated proppant, and degradable particulates, wherein the coated proppant comprise proppant coated with a degradable material; introducing the fracturing fluid into the ultra-low permeability subterranean formation at a rate and pressure above a fracture gradient of the ultra-low permeability subterranean formation; placing the coated proppant and the degradable particulates into at least one fracture of the interconnected fractures so as to form a temporarily impermeable proppant pack comprising the coated proppant and the degradable particulates therein and reduce or prevent the extension of the fracture; reducing the pressure below the fracture gradient; and degrading the degradable particulates and the degradable material coating the coated proppant so as to cause the temporarily impermeable proppant pack to become a permeable proppant pack. ### Claim 8 (depends on 7) The method of claim 7 wherein the temporarily impermeable proppant pack is capable of reducing flow by at least 75% at a differential pressure of at least about 100 psi. ### Claim 9 (depends on 7) The method of claim 7 wherein the permeable proppant pack is capable of allowing at least 75% flow at a differential pressure of at least about 500 psi. ### Claim 10 (depends on 7) The method of claim 7 wherein the degradable material is selected from the group consisting of a poly(hydroxyl alkanoate); a poly(alpha-hydroxy) acid; a poly(beta-hydroxy alkanoate); a poly(omega-hydroxy alkanoate); a poly(alkylene dicarboxylate; a polyanhydride; a poly(orthoester); a polycarbonate; an aliphatic polyester; a poly(lactide); a poly(glycolide); a poly(hydroxybutyrate); a poly(anhydride); an aliphatic polycarbonate; a poly(amino acid); a poly(ethylene oxide); a polyphosphazene; any derivatives thereof; and any combinations thereof. ### Claim 11 (depends on 7) The method of claim 7 wherein the degradable material further comprises a plasticizer selected from the group consisting of polyethylene glycol; polyethylene oxide; oligomeric lactic acid; a citrate ester; a glucose monoester; a partially fatty acid ester; polyethylene glycol monolaurate; triacetin; poly(e-caprolactone); poly(hydroxybutyrate); glycerin-l-benzoate-2,3-dilaurate; glycerin-2-benzoate-l,3-dilaurate; bis(butyl diethylene glycol)adipate; ethylphthalylethyl glycolate; glycerin diacetate monocaprylate; diacetyl monoacyl glycerol; polypropylene glycol; poly(propylene glycol)dibenzoate; dipropylene glycol dibenzoate; glycerol; ethyl phthalyl ethyl glycolate; poly(ethylene adipate)distearate; di-iso-butyl adipate; any derivatives thereof; and combinations thereof. ### Claim 12 (depends on 7) The method of claim 7 wherein the degradable particulate is a solid particulate formed from a material selected from the group consisting of a poly(hydroxyl alkanoate); a poly(alpha-hydroxy) acid; a poly(beta-hydroxy alkanoate); a poly(omega-hydroxy alkanoate); a poly(alkylene dicarboxylate; a polyanhydride; a poly(orthoester); a polycarbonate; an aliphatic polyester; a poly(lactide); a poly(glycolide); a poly(hydroxybutyrate); a poly(anhydride); an aliphatic polycarbonate; a poly(amino acid); a poly(ethylene oxide); a polyphosphazene; a dehydrated salt; any derivatives thereof; and any combinations thereof. ### Claim 13 (depends on 7) The method of claim 7 wherein the degradable material coating the proppant differs in composition from the degradable particulate. ### Claim 14 A method of treating an ultra-low permeability subterranean formation having a fracture complexity comprising interconnected fractures comprising: providing a fracturing fluid comprising a base fluid, coated proppant, and coated degradable particulates, wherein the coated proppant comprise proppant coated with a first degradable material, and wherein the coated degradable particulates comprise degradable particulates coated second degradable material; introducing the fracturing fluid into the ultra-low permeability subterranean formation at a rate and pressure above a fracture gradient of the ultra-low permeability subterranean formation; placing the coated proppant and the coated degradable particulates into at least one fracture of the interconnected fractures so as to form a temporarily impermeable proppant pack comprising the coated proppant and the coated degradable particulates therein and reduce or prevent the extension of the fracture; reducing the pressure below the fracture gradient; and degrading the first and second degradable material coating the coated proppant and the coated degradable particulates, so as to cause the temporarily impermeable proppant pack to become a permeable proppant pack. ### Claim 15 (depends on 14) The method of claim 14 wherein the temporarily impermeable proppant pack is capable of reducing flow by at least 75% at a differential pressure of at least about 100 psi. ### Claim 16 (depends on 14) The method of claim 14 wherein the permeable proppant pack is capable of allowing at least 75% flow at a differential pressure of at least about 500 psi. ### Claim 17 (depends on 14) The method of claim 14 wherein the first and second degradable material is selected from the group consisting of a poly(hydroxyl alkanoate); a poly(alpha-hydroxy) acid; a poly(beta-hydroxy alkanoate); a poly(omega-hydroxy alkanoate); a poly(alkylene dicarboxylate; a polyanhydride; a poly(orthoester); a polycarbonate; an aliphatic polyester; a poly(lactide); a poly(glycolide); a poly(hydroxybutyrate); a poly(anhydride); an aliphatic polycarbonate; a poly(amino acid); a poly(ethylene oxide); a polyphosphazene; any derivatives thereof; and any combinations thereof. ### Claim 18 (depends on 14) The method of claim 14 wherein the degradable particulate is a solid particulate formed from a material selected from the group consisting of a poly(hydroxyl alkanoate); a poly(alpha-hydroxy) acid; a poly(beta-hydroxy alkanoate); a poly(omega-hydroxy alkanoate); a poly(alkylene dicarboxylate; a polyanhydride; a poly(orthoester); a polycarbonate; an aliphatic polyester; a poly(lactide); a poly(glycolide); a poly(hydroxybutyrate); a poly(anhydride); an aliphatic polycarbonate; a poly(amino acid); a poly(ethylene oxide); a polyphosphazene; any derivatives thereof; and any combinations thereof. ### Claim 19 (depends on 14) The method of claim 14 wherein the first and second degradable material differ in composition from each other. ### Claim 20 (depends on 14) The method of claim 14 wherein the second degradable material differs in composition from the degradable particulates.