최소 단어 이상 선택하여야 합니다.
최대 10 단어까지만 선택 가능합니다.
다음과 같은 기능을 한번의 로그인으로 사용 할 수 있습니다.
NTIS 바로가기다음과 같은 기능을 한번의 로그인으로 사용 할 수 있습니다.
DataON 바로가기다음과 같은 기능을 한번의 로그인으로 사용 할 수 있습니다.
Edison 바로가기다음과 같은 기능을 한번의 로그인으로 사용 할 수 있습니다.
Kafe 바로가기국가/구분 | United States(US) Patent 등록 |
---|---|
국제특허분류(IPC7판) |
|
출원번호 | US-0769442 (2013-02-18) |
등록번호 | US-9809737 (2017-11-07) |
발명자 / 주소 |
|
출원인 / 주소 |
|
대리인 / 주소 |
|
인용정보 | 피인용 횟수 : 0 인용 특허 : 310 |
An embodiment comprises a method of treating a subterranean formation comprising: providing a treatment fluid comprising a kiln dust, biowaste ash, and water; and introducing the treatment fluid into a subterranean formation. Another embodiment comprises a method of cementing comprising: introducing
An embodiment comprises a method of treating a subterranean formation comprising: providing a treatment fluid comprising a kiln dust, biowaste ash, and water; and introducing the treatment fluid into a subterranean formation. Another embodiment comprises a method of cementing comprising: introducing a cement composition into a subterranean formation, wherein the cement composition comprises a kiln dust, biowaste ash, and water; and allowing the cement composition to set in the subterranean formation. Yet another embodiment comprises a method comprising: providing a spacer fluid comprising biowaste ash and water; introducing the spacer fluid into a well bore to displace at least a portion of a first fluid from the well bore; and introducing a cement composition into the well bore, wherein the spacer fluid separates the cement composition and the first fluid.
1. A method of treating a subterranean formation comprising: identifying a first yield point of a fluid in a wellbore;providing a treatment fluid comprising a kiln dust, biowaste ash, and water;adjusting a yield point of the treatment fluid to be greater than the first yield point, wherein adjusting
1. A method of treating a subterranean formation comprising: identifying a first yield point of a fluid in a wellbore;providing a treatment fluid comprising a kiln dust, biowaste ash, and water;adjusting a yield point of the treatment fluid to be greater than the first yield point, wherein adjusting comprises adjusting an amount of kiln dust, biowaste ash, or both included in the treatment fluid;wherein the biowaste ash comprises plant- or animal-derived waste products, wherein the plant-derived waste products are selected from the group consisting of sugar cane ash, wood ash, tree leave ash, corn cob ash, rice hull ash, grain ash, grain hull ash, grain husk ash, and combinations thereof and wherein the biowaste ash is present in an amount of about 1% to about 65% by weight of the treatment fluid;introducing the treatment fluid into a subterranean formation; andwherein the treatment fluid has a transition time to progress from a static gel strength of about 100 lbf/100 ft2 to about 500 lbf/100 ft2 at well bore conditions of about 45 minutes or less. 2. The method of claim 1 wherein the biowaste ash further comprises at least one biowaste ash selected from the group consisting of additional agricultural waste ash, municipal waste ash, municipal solid waste ash, waste-water treatment waste ash, animal waste ash, non-human ash, non-animal industrial waste ash, and combinations thereof. 3. The method of claim 1 wherein the biowaste ash comprises biowaste that was burned at a temperature of about 400° C. to about 900° C. for a time period of from about 2 hours to about 8 hours. 4. The method of claim 1 wherein the kiln dust is a partially calcined kiln feed removed from a gas stream comprising SiO2, Al2O3, Fe2O3, CaO, MgO, SO3, Na2O, and K2O. 5. The method of claim 1 wherein the kiln dust comprises cement kiln dust. 6. The method of claim 1 wherein the treatment fluid further comprises at least one component selected from the group consisting of fly ash, a natural pozzolan, metakaolin, shale, calcined shale, slag, zeolite, pumice, perlite, lime, rice husk ash, crystalline silica, amorphous silica, fumed silica, a salt, fiber, hydratable clay, a microsphere, pumicite, diatomaceous earth, an elastomer, a resin, latex, and combinations thereof. 7. The method of claim 1 wherein the treatment fluid further comprises at least one additive selected from the group consisting of a strength-retrogression additive, a set accelerator, a set retarder, a weighting agent, a lightweight additive, a gas-generating additive, a mechanical-property-enhancing additive, a lost-circulation material, a filtration-control additive, a dispersant, a fluid loss control additive, a defoaming agent, a foaming agent, a thixotropic additive, an oil-swellable material, a water-swellable material, and combinations thereof. 8. The method of claim 1 wherein the treatment fluid is a spacer fluid, the spacer fluid separating a first fluid from a second fluid in a well bore penetrating the subterranean formation. 9. The method of claim 8 wherein the kiln dust comprises cement kiln dust. 10. The method of claim 9 wherein the cement kiln dust is present in an amount of about 1% to about 100% by weight of the spacer fluid. 11. A method comprising: identifying a first yield point of a first fluid in a wellbore;providing a spacer fluid comprising biowaste ash and water;adjusting a yield point of the spacer fluid to be greater than the first yield point, wherein adjusting comprises adjusting an amount of kiln dust, biowaste ash, or both included in the spacer fluid;wherein the biowaste ash comprises plant- or animal-derived waste products, wherein the plant-derived waste products are selected from the group consisting of sugar cane ash, wood ash, tree leave ash, corn cob ash, rice hull ash, grain ash, grain husk ash, grain hull ash, orchard ash, vine trimming ash, grass ash, straw ash, ground nut shell ash, legume ash, and combinations thereof and wherein the biowaste ash is present in an amount of about 20% to about 65% by weight of the spacer fluid;introducing the spacer fluid into a well bore to displace at least a portion of the first fluid from the well bore;wherein the spacer fluid has a transition time to progress from a static gel strength of about 100 lbf/10 ft2 to about 500 lbf/100 ft2 at well bore conditions of about 45 minutes or less; andintroducing a cement composition into the well bore, wherein the spacer fluid separates the cement composition and the first fluid. 12. The method of claim 11 wherein the first fluid comprises a drilling fluid. 13. The method of claim 12 wherein the drilling fluid is an aqueous-based drilling fluid. 14. The method of claim 11 wherein the biowaste ash further comprises at least one biowaste ash selected from the group consisting of additional agricultural waste ash, municipal waste ash, municipal solid waste ash, waste-water treatment waste ash, animal waste ash, non-human ash, non-animal industrial waste ash, and combinations thereof. 15. The method of claim 11 wherein the biowaste ash further comprises additional agricultural waste ash. 16. The method of claim 11 wherein the biowaste ash further comprises municipal waste ash. 17. The method of claim 11 wherein the biowaste ash is present in the spacer fluid in an amount of about 1% to about 25% by weight of the spacer fluid. 18. The method of claim 11 wherein the biowaste ash is present in the spacer fluid in an amount of about 1% to about 10% by weight of the spacer fluid. 19. The method of claim 11 wherein the spacer fluid further comprises at least one additive selected from the group consisting of a clay, a hydratable polymer, guar gum, an organic polymer, a surfactant, crystalline silica, amorphous silica, fumed silica, a salt, a fiber, a microsphere, fly ash, rice husk ash, any combination thereof. 20. The method of claim 11 wherein the spacer fluid further comprises at least one additive selected from the group consisting of a free water control additive, a weighting agent, a viscosifying agent, a fluid loss control additive, a lost circulation material, a filtration control additive, a dispersant, a defoamer, a corrosion inhibitor, a scale inhibitor, a formation conditioning agent, and any combination thereof. 21. The method of claim 11 wherein the spacer fluid is foamed and further comprises a gas and a foaming and stabilizing surfactant composition. 22. The method of claim 11 wherein at least a portion of the spacer fluid remains in the well bore and consolidates in the well bore. 23. The method of claim 22 wherein the portion of the spacer fluid has a zero gel time of about 4 hours or less or a transition time of about 45 minutes or less. 24. The method of claim 22 further comprising running a bond log to measure consolidation properties of the portion of the spacer fluid in the well bore. 25. The method of claim 11 wherein the spacer fluid further comprises a partially calcined kiln feed removed from a gas stream comprising SiO2, Al2O3, Fe2O3, CaO, MgO, SO3, Na2O, and K2O.
Copyright KISTI. All Rights Reserved.
※ AI-Helper는 부적절한 답변을 할 수 있습니다.