(US20190144737) Pre-flush for oil foamers 机翻标题: 暂无翻译,请尝试点击翻译按钮。

源语言标题
(US20190144737) Pre-flush for oil foamers
公开号/公开日
US20190144737 / 2019-05-16
申请号/申请日
US16/171,684 / 2018-10-26
发明人
MORALES ROSANELQUINTERO LIRIOLEHRER SCOTT ERIC;
申请人
BAKER HUGHES;
主分类号
IPC分类号
C09K-008/584 C09K-008/588 C09K-008/594 E21B-043/12 E21B-043/16
摘要
(US20190144737) A method of enhancing oil or gas production comprises injecting into a well penetrating a subterranean formation a pre-flush fluid to increase water wettability of the well, the subterranean formation, a flowline, or a combination comprising at least one of the foregoing; and injecting into the well a foamer composition.
机翻摘要
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地址
代理人
代理机构
;
优先权号
2017US-62585134 2018US-16171684
主权利要求
(US20190144737) What is claimed is: 1. A method of enhancing oil or gas production, the method comprising:   injecting into a well penetrating a subterranean formation a pre-flush fluid to increase water wettability of the well, the subterranean formation, a flowline, or a combination comprising at least one of the foregoing; and   injecting into the well a foamer composition. 2. The method of claim 1, wherein the foamer composition is injected after the pre-flush fluid. 3. The method of claim 1, wherein the foamer composition contacts the wellbore fluid in the well to decrease the density of a wellbore fluid. 4. The method of claim 1, further comprising conveying a wellbore fluid out of the well. 5. The method of claim 4, wherein the wellbore fluid is conveyed out of the well together with a lift gas. 6. The method of claim 5, wherein the lift gas is injected into the well and comprises air, carbon dioxide, methane, ethane, propane, nitrogen, or a combination comprising at least one of the foregoing. 7. The method of claim 5, wherein the lift gas is naturally occurring and comprises carbon dioxide, natural gas, or a combination comprising at least one of the foregoing. 8. The method of claim 4, wherein the wellbore fluid is a crude oil. 9. The method of claim 4, wherein the wellbore fluid has an API density of less than 45. 10. The method of claim 4, wherein the wellbore fluid has an API density of 45 to 55. 11. The method of claim 4, wherein the wellbore fluid has a water cut of equal to or less than 75%. 12. The method of claim 1, wherein the pre-flush fluid is a single phase fluid, a microemulsion, or a combination thereof 13. The method of claim 1, wherein a pre-flush fluid is a single phase fluid comprising a surfactant, a solvent, and a co-solvent. 14. The method of claim 13, wherein:   the surfactant in the single phase fluid comprises:    nonionic surfactants having an HLB between about 9 and about 14,    anionic surfactants comprising oxyalkylated ether sulfates, alkyl aryl sulfates, disulfonates, sulfosuccinates, sulfonates, carboxylates, or a combination comprising at least one of the foregoing,    cationic surfactants,    gemini surfactants, betaines, amino-acids, or a combination comprising at least one of the foregoing;   the solvent in the single phase fluid comprises an aromatic solvent, aliphatic solvent, or a combination comprising at least one of the foregoing; and   the co-solvent in the single phase fluid comprises glycol ethers, methyl 2-pyrrolidone, methanol, isopropyl alcohol, butanol, pentanol, hexanol, isooctyl alcohol and their isomers, blends of C1-8 alcohols, or a combination comprising at least one of the foregoing. 15. The method of claim 14, wherein the pre-flush fluid comprises:   about 5 to about 40 wt % of the solvent which comprises an aromatic solvent;   about 5 to about 25 wt % of the surfactant which comprises a blend of polyoxyalkylene sulfate and alcohol ethoxylate;   about 5 to about 30 wt % of the co-solvent which comprises glycol ether, an aliphatic alcohol, or a combination thereof; and   about 40 wt % to about 60 wt % of a brine,   each based on a total weight of the pre-flush fluid. 16. The method of claim 1, wherein the pre-flush fluid is a microemulsion comprising a polar fluid, a non-polar fluid, and a surfactant. 17. The method of claim 1, wherein the pre-flush fluid injected into the well comprises in-situ emulsion-forming components which include a surfactant, a polar fluid, and optionally a co-solvent, and a co-surfactant. 18. The method of claim 17, wherein the surfactant comprises non-ionic surfactants, anionic surfactants, cationic surfactants, amphoteric surfactants, extended surfactants containing a non-ionic spacer-arm central extension and an ionic or nonionic polar group, or a combination comprising at least one of the foregoing,   the nonionic surfactants comprising alkyl polyglycosides, sorbitan esters, methyl glucoside esters, polyglycol esters, or alcohol ethoxylates;   the anionic surfactants comprising alkali metal alkyl sulfates, alkyl or alkylaryl sulfonates, linear or branched alkyl ether sulfates and sulfonates, alcohol polypropoxylated sulfates, alcohol polyethoxylated sulfates, alkyl or alkylaryl disulfonates, alkyl disulfates, alkyl sulphosuccinates, alkyl ether sulfates, linear and branched ether sulfates; and   the cationic surfactants comprising arginine methyl esters, alkanolamines, and alkylenediamides, and   the extended surfactants having propoxylated or ethoxylated spacer arms. 19. The method of claim 1, wherein the foamer composition comprises a silicone surfactant and an additive comprising one or more of the following: a diluent; a foamer solvent; or a second foamer surfactant different from the silicone surfactant. 20. The method of claim 1 further comprising recovering the wellbore fluid in a foamed state. 21. The method of claim 1, wherein the pre-flush fluid and the foamer composition are injected via an umbilical, capillary string, gas lift, an annulus for wells without a packer, or a combination comprising at least one of the foregoing. 22. The method of claim 1, wherein the pre-flush fluid and the foamer composition are applied in a batch treatment. 23. The method of claim 1, wherein the pre-flush fluid and the foamer composition are applied in a continuous treatment. 24. A method of mitigating liquid loading in an oil well penetrating a subterranean formation, the method comprising:   injecting into the oil well a pre-flush fluid to increase water wettability of the oil well, the subterranean formation, a flowline, or a combination comprising at least one of the foregoing, the pre-flush fluid being a single phase fluid, a microemulsion, or a combination thereof;   injecting a foamer composition into the oil well subsequent to injecting the pre-flush fluid; and   injecting a lift gas into the well or using a naturally occurring gas in the well to remove a wellbore fluid out of the well. 25. The method of claim 24, wherein the pre-flush fluid is a single phase fluid comprising:   about 5 to about 40 wt % of a solvent;   about 5 to about 25 wt % of a surfactant; and   about 5 to about 30 wt % of a co-solvent;   each based on a total weight of the pre-flush fluid,   the surfactant comprising:    nonionic surfactants having an HLB between about 9 and about 14,    anionic surfactants selected from the group comprising oxyalkylated ether sulfates, alkyl aryl sulfates, disulfonates, sulfosuccinates,   sulfonates, carboxylates, or a combination comprising at least one of the foregoing,    cationic surfactants,    gemini surfactants, betaines, amino-acids, or a combination comprising at least one of the foregoing;   the solvent comprising an aromatic solvent, aliphatic solvent, or a combination comprising at least one of the foregoing; and   the co-solvent comprising glycol ethers, methyl 2-pyrrolidone, methanol, isopropyl alcohol, butanol, pentanol, hexanol, isooctyl alcohol and their isomers, blends of C1-8 alcohols, or a combination comprising at least one of the foregoing. 26. The method of claim 24, wherein the pre-flush fluid is a micro emulsion formed above the well or in-situ in the well.
法律状态
PENDING
专利类型码
A1
国别省市代码
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