High rate stimulation method for deep, large bore completions
IPC분류정보
국가/구분
United States(US) Patent
등록
국제특허분류(IPC7판)
E21B-043/26
E21B-034/14
E21B-043/114
E21B-043/267
출원번호
US-0358079
(2009-01-22)
등록번호
US-8960292
(2015-02-24)
발명자
/ 주소
Smith, Malcolm
East, Jr., Loyd
Stanojcic, Milorad
출원인 / 주소
Halliburton Energy Services, Inc.
대리인 / 주소
Wustenberg, John W.
인용정보
피인용 횟수 :
0인용 특허 :
116
초록▼
A method of servicing a wellbore comprising inserting a first tubing member into the wellbore, wherein a manipulatable fracturing tool is coupled to the first tubing member and comprises one or more ports configured to alter a flow of fluid through the manipulatable fracturing tool, positioning the
A method of servicing a wellbore comprising inserting a first tubing member into the wellbore, wherein a manipulatable fracturing tool is coupled to the first tubing member and comprises one or more ports configured to alter a flow of fluid through the manipulatable fracturing tool, positioning the manipulatable fracturing tool proximate to a formation zone, manipulating the manipulatable fracturing tool to establish fluid communication between the flowbore of the first tubing member and the wellbore, introducing a first component of a composite fluid into the wellbore via the flowbore of the first tubing member, introducing a second component of the composite fluid into the wellbore via an annular space formed by the first tubing member and the wellbore, mixing the first component with the second component within the wellbore, and causing a fracture to form or be extended within the formation zone.
대표청구항▼
1. A method of servicing a wellbore comprising; inserting a first tubing member having a flowbore into the wellbore having disposed therein a casing string, wherein a manipulatable fracturing tool, or a component thereof, is coupled to the first tubing member and wherein the manipulatable fracturing
1. A method of servicing a wellbore comprising; inserting a first tubing member having a flowbore into the wellbore having disposed therein a casing string, wherein a manipulatable fracturing tool, or a component thereof, is coupled to the first tubing member and wherein the manipulatable fracturing tool comprises a first one or more ports and a second one or more ports configurable to alter a flow of fluid through the minipulable fracturing tool;positioning the manipulatable fracturing tool within the casing string within the wellbore proximate to a formation zone to be serviced;introducing an obturating member into the first tubing member;forward-circulating the obturating member to engage an obturating structure within the manipultable fracturing tool and thereby manipulate the manipulatable fracturing tool such that there is fluid communication between the flowbore of the first tubing member and the wellbore via the first one or more ports and such that there is not fluid communication between the flowbore of the first tubing member and the wellbore via the second one or more ports;emitting a first fluid from the first one or more ports;reverse circulating the obturating member to disengage the obturating member from the obturating structure and thereby further manipulate the manipulatable fracturing tool such that there is fluid communication between the flowbore of the first tubing member and the wellbore via the first one or more ports and the second one or more ports;introducing at least a portion of a first component of a composite fluid into the wellbore at a first rate via the flowbore of the first tubing member, the first one or more ports, and the second one or more ports;introducing a second component of the composite fluid into the wellbore at a second rate via an annular space formed by the first tubing member and the wellbore;mixing the first component of the composite fluid with the second component of the composite fluid within the welibort; andintroducing the comrposite fluid into the fonnation zone. 2. The method of claim 1,wherein at least one of the first one or more ports of the manipulatable fracturing tool comprises a hydrajetting nozzle, wherein the engagement of the obturating mi-mber operates to direct fluid flow through the hvdraletting nozzle. 3. The method claim 2 wherein the fluid flow through the hydraletting nozzle is sufficient to depide a liner, a casing, the formation zone, or combinations thereof. 4. The method of claim 3, wherein the fluid flow through the hydrajetting nozzle is sufficient to initiate a fracture in the formation zone. 5. The method of claim 2, wherein disengaging the obturating member operates to provide a higher volume flowpath through the: second one or more ports in comparison to the flowpatia through the first one or more ports for emission of fluid from the tool into the wellbore. 6. The method of claim 5 wherein the fluid emitted from the tool is utilized to initiate a fracture or extend a fracture in the formation zone. 7. The method of claim 1, wherein the first component of the composite fluid comprises a concentrated acid component,wherein the second component of the composite fluid comprises a diluent, andwherein the composite fluid comprises an acidizing solution that is formed within the wellbore proximate to the formation zone to effectuate an acidizing operation. 8. The method of claim 1, wherein the first component of the composite fluid comprises a concentrated isolation fluid component,wherein the second component of the composite fluid comprises a diluent, andwherein the composite fluid comprises an isolation fluid that is formed within the wellbore proximate to the formation zone to effectuate an isolation operation. 9. The method of claim 1, wherein the first component of the composite fluid comprises a concentrated proppant-laden fluid,wherein the second component of the composite fluid comprises a diluent, andwherein the composite fluid comprises a fracturing fluid that is formed within the wellbore proximate to the formation zone to effectuate a fracturing operation. 10. The method of claim 1, wherein the first one or more ports of the manipulatable fracturing tool comprise a higher pressure port in comparison to the second one or more ports, and wherein the second one or more ports of the manipulatable fracturing tool comprise a higher volume, port in comparison to the first one or more ports. 11. The wellbore servicing system of claim 1, wherein the manipulatable fracturing tool is transitionable while in the wellbore from a first configuration in which the fluid is communicated via the first one or more ports to degrade a liner, a casing, a formation zone, or combinations thereof toa second configuration in which the fluid is communicated via the first one of more ports and the second one or more ports to initiate or extend fractures in the formation zone. 12. The method of claim 10, wherein forward-circuating the obturatin member to engage an obturating structure operates to direct a fluid flow through the higher pressure port. 13. The method of claim 10, wherein reverse circulating the obturating member to disengage the obturating member from the obturating structure operates to allow a fluid flow through the higher volume port. 14. The wellbore servicing system of claim 1, wherein at least one of the first one or more ports is fitted with a nozzle. 15. The method of claim 1, further comprising varying a rate at which the first component of the composite fluid is introduced into me wellbore via the flowbore of the first tubing member, varying a rate at which the second component of the composite fluid is introduced into the wellbore via the annular space, or combinations thereof. 16. The method of claim 15, wherein varying the rate at which the first component of the composite fluid is introduced into the wellbore via the flowbore of the first tubing member, varying the rate at which the second component of the composite fluid is introduced into the wellbore via the annular space, or combinations thereof is effective to vary the concentration of an acid, a proppant a gel, an abrasive material within the composite fluid. 17. The method of claim 1, further comprising varying the concentration of an acid, a proppant, a gel, an abrasive material within the composite fluid without changing the composition of either the first component or the second component of the composite fluid. 18. The. method of claim 1, wherein the first tubing member comprises coiled tubing. 19. A method of servicing a wellbore comprising: inserting a casing string having a flowbore into the wellbore, wherein a plurality of manipulatable fracturing tools are coupled to the casing string and wherein the manipulatable fracturing tools comprise one or more ports configured to alter a flow of fluid through the manipulatable fracturing tool;positioning the manipulatable fracturing tools proximate to zones in a formation to be fractured;inserting a first tubing member within the casing string, wherein a shifting tool is attached to the first tubing member, wherein the shifting tool further comprise: a baffle plate;an obturating member seat;an indexing check valve;or combinations thereof;positioning the shifting tool proximate to at least one of the manipulatable fracturing tools;actuting the shifting tool such that the actuation of the shifting tool engages the manipulatable fracturing tool such that the manipulatable fracturing tool may be manipulated to establish fluid communication between the flowbore of the first tubing member and the wellbore, wherein actuating the shifting tool comprises causing introducing an obturating member via the flowbore of the first tubing member to engage the baffle plate, the obturating member seat, the indexing check valve, or combination thereof, wherein the engagement of the obturating member actuates the shifting tool;disengaging the obturating member from the shifting tool and removing the obturating member from the flowbore of the first tubing member;after removing the obturating member, introducing a first component of a composite fluid into the wellboreore via the flowbore of the first tubing member at a first rate;introducing a second component of the composite fluid into the wellbore via annular space formed by the first tubing member and the casing string at a second rate;mixing the first component of the composite fluid with the second component of the composite fluid within the wellbore; andintroducing the composite fluid into the formation, thereby causing a fracture to form or be extended within the formation. 20. The method of claim 19, wherein the first tubing member comprises an axial flowpath divided into two or more separate flowpaths. 21. The method of claim 19, further comprising isolating the zones in the formation. 22. The method of claim 21, wherein the zones in the formation are isolated via swellable packers disposed about the casing string between each of the plurality of manipulatable fracturing tools. 23. The method of claim 19, wherein the first tubing member comprises coiled tubing.
연구과제 타임라인
LOADING...
LOADING...
LOADING...
LOADING...
LOADING...
이 특허에 인용된 특허 (116)
Jim B. Surjaatmadja ; Gary T. Keene, Apparatus and method for connecting casing to lateral casing using thermoset plastic molding.
Nguyen,Philip D.; Todd,Bradley L.; Munoz, Jr.,Trinidad, Compositions and methods for improving proppant pack permeability and fracture conductivity in a subterranean well.
Willberg, Dean M.; Bulova, Marina; Fredd, Christopher N.; Vostrukhov, Alexey; Boney, Curtis L.; Lassek, John; Hoefer, Ann M. W.; Sullivan, Philip F., Degradable material assisted diversion or isolation.
Bigg Donald M. ; Sinclair Richard G. ; Lipinsky Edward S. ; Litchfield John H. ; Allen Billy R., Degradation control of environmentally degradable disposable materials.
Earl Robert B. (Tulsa County OK) Larson David B. (Tulsa County OK) Nguyen Huy X. (Tulsa County OK), Fracturing fluids containing bouyant inorganic diverting agent and method of use in hydraulic fracturing of subterranean.
Parker, Mark A.; Nguyen, Philip D.; Weaver, Jimmie D.; Slabaugh, Billy F.; Segura, Jr., Michael, High porosity fractures and methods of creating high porosity fractures.
Surjaatmadja, Jim B.; Howell, Matt T.; Case, Leonard; Robinson, Lonnie R., Method and apparatus for orchestration of fracture placement from a centralized well fluid treatment center.
Randy C. Tolman ; Lawrence O. Carlson ; David A. Kinison ; Kris J. Nygaard ; Glenn S. Goss ; William A. Sorem ; Lee L. Shafer, Method and apparatus for stimulation of multiple formation intervals.
Cheng, Alick; Surjaatmadja, Jim B.; Rees, Matthew J.; Khallad, Abraham; Rispler, Keith A., Method for acid stimulating a subterranean well formation for improving hydrocarbon production.
Venditto James J. (Duncan OK) McMechan David E. (Marlow OK) Blauch Matthew E. (Duncan OK), Method for optimizing hydraulic fracturing through control of perforation orientation.
Erbstoesser Steven R. (Missouri City TX) Cooke ; Jr. Claude E. (Houston TX) Sinclair Richard G. (Columbus OH) Epstein Michael M. (Columbus OH), Method for reducing the permeability of subterranean formations.
Lee Wellington S. (Duncan OK) McMechan David E. (Marlow OK) McDaniel Billy W. (Marlow OK), Method of evaluating fluid loss in subsurface fracturing operations.
Soliman Mohamed Y. (Lawton OK) Venditto James J. (Duncan OK) Daneshy A. Ali (Leiden NLX), Method to control fracture orientation in underground formation.
Soliman, Mohamed Y.; East, Loyd E.; Stegent, Neil A.; Ansah, Joseph, Methods and systems for evaluating and treating previously-fractured subterranean formations.
Nguyen,Philip D.; Dusterhoft,Ronald G.; Surjaatmadja,Jim B.; East, Jr.,Loyd E., Methods of controlling sand and water production in subterranean zones.
Pauls, Richard W.; Surjaatmadja, Jim B.; Welton, Thomas D., Methods of fracturing a subterranean formation using a jetting tool and a viscoelastic surfactant fluid to minimize formation damage.
Nguyen,Philip D.; Weaver,Jimmie D.; Gibson,Ron A.; Barton,Johnny A., Methods of hydraulic fracturing and of propping fractures in subterranean formations.
Willett, Ronald M.; Surjaatmadja, Jim B.; McDaniel, Billy W.; Farabee, Leldon Mark; Adams, David M.; East, Lloyd E., Methods of isolating hydrajet stimulated zones.
Willett,Ronald M.; Surjaatmadja,Jim B.; McDaniel,Billy W.; Farabee,Leldon Mark; Adams,David M.; East,Loyd E., Methods of isolating hydrajet stimulated zones.
Rispler, Keith A.; East, Loyd E.; Todd, Bradley L.; McMechan, David E.; McMechan, legal representative, Corine, Methods of setting particulate plugs in horizontal well bores using low-rate slurries.
McDaniel, Billy W.; Slabaugh, Billy F.; Lehman, Lyle V.; Weaver, Jimmie D., Methods to increase recovery of treatment fluid following stimulation of a subterranean formation comprising cationic surfactant coated particles.
McDaniel, Billy W.; Slabaugh, Billy F.; Lehman, Lyle V.; Weaver, Jimmie D., Methods to increase recovery of treatment fluid following stimulation of a subterranean formation comprising in situ fluorocarbon coated particles.
Soliman Mohamed Yousef ; Creel Prentice G. ; Rester Steve ; Johnson Michael H. ; East ; Jr. Loyd E. ; Everett Don M., Proactive conformance for oil or gas wells.
Vogt ; Jr. Thomas C. (Littleton CO) Hale Mitchell W. (Seal Beach CA) Sellers Jay R. (Bakersfield CA), Sequential hydraulic fracturing of a subsurface formation.
Surjaatmadja, Jim B.; Cheng, Alick; Rispler, Keith A., System and method for fracturing a subterranean well formation for improving hydrocarbon production.
Scott ; III George L. (100 N. Pennsylvania Roswell NM 88201), Systems of injecting phenolic resin activator during subsurface fracture stimulation for enhanced oil recovery.
Szarka David D. (Duncan OK) Sullaway Bob L. (Duncan OK) Brandell John T. (Duncan OK) Schwegman Steven L. (Duncan OK), Well completions using casing valves.
※ AI-Helper는 부적절한 답변을 할 수 있습니다.