Methods and compositions for selectively dissolving sandstone formations
원문보기
IPC분류정보
국가/구분
United States(US) Patent
등록
국제특허분류(IPC7판)
E21B-043/27
E21B-043/25
출원번호
US-0767579
(2007-06-25)
등록번호
US-7431089
(2008-10-07)
발명자
/ 주소
Couillet,Isabelle
Still,John W.
출원인 / 주소
Schlumberger Technology Corporation
대리인 / 주소
Cate,David
인용정보
피인용 횟수 :
8인용 특허 :
20
초록▼
In a method of treating a sandstone-containing subterranean formation penetrated by a wellbore, a slurry of a carrier fluid containing a surface modification agent of at least one of a hydrolyzable organosilicon compound, a phosphonate compound or a combination of these is formed. The slurry is intr
In a method of treating a sandstone-containing subterranean formation penetrated by a wellbore, a slurry of a carrier fluid containing a surface modification agent of at least one of a hydrolyzable organosilicon compound, a phosphonate compound or a combination of these is formed. The slurry is introduced into the wellbore at or above the fracture pressure of the formation. A sandstone-dissolving material is introduced into the wellbore with or subsequent to introduction of the slurry. The surface modification agent may be encapsulated within an encapsulating material. A composition for use in treating sandstone-containing subterranean formations is also provided. The composition includes an aqueous carrier fluid containing an encapsulated surface modification agent of at least one of a hydrolysable organosilicon compound and a phosphonate compound that is encapsulated within an encapsulating material.
대표청구항▼
We claim: 1. A method of treating a sandstone-containing subterranean formation penetrated by a wellbore comprising: forming a slurry of a carrier fluid containing a surface modification agent of at least one of a hydrolyzable organosilicon compound, a phosphonate compound or a combination thereof;
We claim: 1. A method of treating a sandstone-containing subterranean formation penetrated by a wellbore comprising: forming a slurry of a carrier fluid containing a surface modification agent of at least one of a hydrolyzable organosilicon compound, a phosphonate compound or a combination thereof; introducing the slurry into the wellbore at a pressure at or above the fracture pressure of the formation; and then introducing a sandstone-dissolving material not comprising a surface modification agent into the wellbore subsequent to introduction of the slurry the surface modification agent is an encapsulated surface modification agent that is encapsulated within an encapsulating material. 2. The method of claim 1, wherein: the encapsulating material is at least one of soft plastic, wax, natural or synthetic rubber, latex, vermiculite, polyacrylamide, phenol formaldehyde polymer, nylon, starch, benzoic acid metals, naphthalene, natural or synthetic polymers, natural or synthetic oil. 3. The method of claim 1, wherein: the encapsulated surface modification agent has a particle size of from about 0.1 mm to about 2 mm. 4. A method of acid fracturing and differentially etching regions of fracture surfaces in sandstone formations, said etching providing a conductive path from the fracture tip to the wellbore comprising the steps of a) first injecting a first fluid selected from an aqueous fluid comprising a surface modification material comprising a hydrolyzable organosilicon compound or a mixture of a hydrolyzable organosilicon compound and a phosphonate compound, and a fluid comprising a phosphonate compound, into the fracture at a pressure above fracture pressure, then b) allowing said modification material to adsorb onto portions of the fracture surfaces creating protected portions and non-protected portions of the fracture surfaces, and then c) injecting a second fluid comprising a sandstone-dissolving material, said fluid not comprising a surface modification material, into the wellbore, wherein non-protected areas of the fracture surfaces react with the sandstone-dissolving material and create the conductive path. 5. The method of claim 4, wherein: the sandstone-dissolving material is ammonium bifluoride. 6. The method of claim 4, wherein: the sandstone-dissolving material comprises an acid-based fluid and a hydrogen fluoride source. 7. The method of claim 6, wherein: the acid-based fluid includes hydrochloric acid, nitric acid, hydroiodic acid, hydrobromic acid, sulfuric acid, sulfamic acid, phosphoric acid, formic acid, acetic acid, halogenated derivatives of acetic acid, citric acid, propionic acid, tartaric acid, lactic acid, glycolic acid, aminopolycarboxylic acids, sulfamic acid, malic acid, maleic acid, methylsulfamic acid, chloroacetic acid, 3-hydroxypropionic acid, polyaminopolycarboxylic acid, bisulfate salts and combinations of these. 8. The method of claim 6, wherein: the hydrogen fluoride source is selected from ammonium fluoride, ammonium bifluoride, hydrofluoric acid, fluoroboric acid, hexafluorophosphoric acid, difluorophosphoric acid, fluorosulfonic acid, polyvinylammonium fluoride, polyvinylpyridinium fluoride, pyridinium fluoride, imidazolium fluoride, sodium tetrafluoroborate, ammonium tetrafluoroborate, salts of hexafluoroantimony, polytetrafluoroethylene polymers, and combinations of these. 9. The method of claim 4, wherein: the organosilicon material is at least one of an organosilane, an amine of an organosilane or an ester of organosilane. 10. The method of claim 4, wherein: the organosilicon has a structure represented by the formula Si(OR)3(R'NH2), where R and R' are each organic groups that are the same or different. 11. The method of claim 4, wherein: the phosphonate compound is a least one of a phosphonic acid or a salt or ester of a phosphonic acid. 12. The method of claim 4, wherein: the phosphonate compound has a structure represented by the formula: wherein R1, R2 and R3 is each selected from one of a hydrogen, alkyl, aryl, phosphonate, phosphate, acyl, amine, hydroxyl or carboxyl group, and wherein R4 and R5 is selected from one of hydrogen, sodium, potassium, ammonium or an organic radical. 13. The method of claim 4, wherein: the surface modification agent in the first fluid makes up from about 0.1% to about 30% of the slurry. 14. The method of claim 4, wherein: an increase in the production of fluids from the wellbore follows the introduction of the sandstone-dissolving material. 15. A method of acid fracturing a sandstone-containing subterranean formation penetrated by a wellbore comprising: forming a slurry of an aqueous carrier fluid containing an encapsulated surface modification agent of at least one of a hydrolyzable organosilicon compound or a phosphonate compound encapsulated within an encapsulating material; introducing the slurry into the wellbore above fracture pressure; shutting in said wellbore at or above fracture pressure for at least one hour, thereby allowing said encapsulated modification agent to adsorb onto portions of the fracture surfaces creating protected portions and non-protected portions of the fracture surfaces; and then introducing a sandstone-dissolving material into the wellbore.
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