For wellbore fluid treatment, sliding sleeves deploy on tubing in a wellbore annulus. Operators deploy a plug down the tubing to a first sleeve. The plug seats in this first sleeve, and pumped fluid pressure opens the first sleeve and communicates from the tubing to the wellbore annulus. In the annu
For wellbore fluid treatment, sliding sleeves deploy on tubing in a wellbore annulus. Operators deploy a plug down the tubing to a first sleeve. The plug seats in this first sleeve, and pumped fluid pressure opens the first sleeve and communicates from the tubing to the wellbore annulus. In the annulus, the fluid pressure creates a pressure differential between the wellbore annulus pressure and a pressure chamber on second sleeves on the tubing. The resulting pressure differential opens the second sleeves so that fluid pressure from the tubing can communicate through the second open sleeves. Using this arrangement, one sleeve can be opened in a cluster of sleeves without opening all of them at the same time. The deployed plug is only required to open the fluid pressure to the annulus by opening the first sleeve. The pressure chambers actuate the second sleeves to open up the tubing to the annulus.
대표청구항▼
1. A wellbore fluid treatment method, comprising: deploying a plurality of sliding sleeves on a tubing string in a wellbore annulus, the sliding sleeves at least including a first sliding sleeve and at least one second sliding sleeve;opening a first housing outlet associated with the first sliding s
1. A wellbore fluid treatment method, comprising: deploying a plurality of sliding sleeves on a tubing string in a wellbore annulus, the sliding sleeves at least including a first sliding sleeve and at least one second sliding sleeve;opening a first housing outlet associated with the first sliding sleeve to communicate fluid pressure from the tubing string to the wellbore annulus by deploying a first plug down the tubing string and pumping fluid pressure in the tubing string;communicating fluid pressure from the tubing string to the wellbore annulus by passing fluid through the open first housing outlet associated with the first sliding sleeve;opening at least one second housing outlet associated with the at least one second sliding sleeve by applying fluid pressure communicated in the wellbore annulus from the first sliding sleeve relative to a pressure chamber on the at least one second sliding sleeve; andcommunicating fluid pressure from the tubing string to the wellbore annulus by passing fluid through the at least one open second housing outlet associated with the at least one second sliding sleeve. 2. The method of claim 1, wherein deploying the plurality of sliding sleeves comprises isolating the wellbore annulus uphole and downhole of the plurality of sliding sleeves on the tubing string. 3. The method of claim 2, wherein isolating the wellbore annulus comprises engaging packing elements on the tubing string uphole and downhole of the sliding sleeves against a sidewall of the wellbore. 4. The method of claim 1, wherein deploying the sliding sleeves comprises deploying the at least one second sliding sleeve uphole of the first sliding sleeve on the tubing string. 5. The method of claim 1, wherein the first sliding sleeve comprises: a movable sleeve being movable from a closed condition to an open condition relative to the first housing outlet; anda seat disposed on the movable sleeve and engaging with the first plug when deployed down the tubing string,the movable sleeve moving to the open condition in response to fluid pressure applied against the seated first plug. 6. The method of claim 1, wherein the at least one second sliding sleeve comprises: a movable sleeve being movable from a closed condition to an open condition relative to the at least one second housing outlet, the movable sleeve moving from the closed condition to the open condition in response to a pressure differential between the wellbore annulus and the pressure chamber, the movable sleeve in the open condition permitting fluid pressure from the tubing string to communicate to the wellbore annulus through the at least one second housing outlet. 7. The method of claim 1, wherein opening the first housing outlet associated with the first sliding sleeve to communicate fluid pressure from the tubing string with the wellbore annulus comprises: engaging the deployed first plug on a seat of a movable sleeve of the first sliding sleeve; andmoving the movable sleeve open relative to the first housing outlet associated with the first sliding sleeve with fluid pressure applied against the seated first plug. 8. The method of claim 1, wherein opening the at least one second housing outlet associated with at least one second sliding sleeve comprises: creating a pressure differential between the wellbore annulus and the pressure chamber of a movable sleeve on the at least one second sliding sleeve; andmoving the movable sleeve open relative to the second housing outlet associated with the at least one second sliding sleeve in response to the created pressure differential. 9. The method of claim 8, wherein creating the pressure differential comprises applying the fluid pressure in the wellbore annulus against the movable sleeve to act against the pressure chamber. 10. The method of claim 1, wherein deploying the sliding sleeves comprise deploying a third sliding sleeve and at least one fourth sliding sleeve uphole from the first sliding sleeve and the at least one second sliding sleeve. 11. The method of claim 10, wherein deploying the sliding sleeves comprises isolating the third sliding sleeve and the at least one fourth sliding sleeves from the first sliding sleeve and the at least one second sliding sleeve in the wellbore annulus. 12. The method of claim 10, wherein the method further comprises: opening the third sliding sleeve to communicate fluid pressure from the tubing string to the wellbore annulus by deploying a second plug down the tubing string and pumping fluid pressure in the tubing string; andopening the at least one fourth sliding sleeve by applying fluid pressure in the wellbore annulus relative to a pressure chamber on the at least one fourth sliding sleeve. 13. The method of claim 1, wherein the tubing string comprises a plurality of the at least one second sliding sleeves, each of the second sliding sleeves having a pressure chamber and each opening in response to a same or different pressure differential between the wellbore annulus and the pressure chamber. 14. A wellbore fluid treatment method, comprising: deploying a plurality of sliding sleeves on a tubing string in a wellbore annulus, the sliding sleeves at least including a first sliding sleeve and at least one second sliding sleeve;seating a plug in the first sliding sleeve;pumping fluid pressure in the tubing string;opening a first housing outlet associated with the first sliding sleeve with fluid pressure applied against the seated plug in the first sliding sleeve;communicating fluid pressure to the wellbore annulus by passing fluid through the open first housing outlet associated with the first sliding sleeve;applying fluid pressure in the wellbore annulus communicated from the open first sliding sleeve relative to a pressure chamber on the at least one second sliding sleeve;opening at least one second housing outlet associated with the at least one second sliding sleeve with a pressure differential between the pressure chamber and the wellbore annulus; andcommunicating fluid pressure to the wellbore annulus by passing fluid through the at least one open second housing outlet associated with the at least one sliding sleeve. 15. The method of claim 14, wherein deploying the plurality of sliding sleeves comprises isolating the wellbore annulus uphole and downhole of the plurality of sliding sleeves on the tubing string. 16. The method of claim 14, wherein deploying the sliding sleeves comprises deploying the at least one second sliding sleeve uphole of the first sliding sleeve on the tubing string. 17. The method of claim 14, wherein opening the first housing outlet associated with the first sliding sleeve comprises: engaging the seated first plug on a seat of a movable sleeve of the first sliding sleeve; andmoving the movable sleeve open relative to the first housing outlet associated with the first sliding sleeve with fluid pressure applied against the seated first plug. 18. The method of claim 14, wherein opening the at least one second housing outlet associated with the at least one second sliding sleeve comprises: creating the pressure differential between the wellbore annulus and the pressure chamber of a movable sleeve on the at least one second sliding sleeve; andmoving the movable sleeve open relative to the second housing outlet associated with the at least one second sliding sleeve in response to the created pressure differential. 19. The method of claim 18, wherein creating the pressure differential comprises applying the fluid pressure in the wellbore annulus against the movable sleeve to act against the pressure chamber. 20. The method of claim 14, wherein the tubing string comprises a plurality of the at least one second sliding sleeves, each of the second sliding sleeves having a pressure chamber and each opening in response to a same or different pressure differential between the wellbore annulus and the pressure chamber. 21. A wellbore fluid treatment apparatus, comprising: a first sliding sleeve disposing on a tubing string in a wellbore and having a first housing outlet, the first sliding sleeve opening the first housing outlet in response to fluid pressure applied down the tubing string, the open first sliding sleeve passing fluid out the open first housing outlet and communicating fluid pressure from the tubing string to a wellbore annulus through the open first housing outlet associated with the first sliding sleeve; andat least one second sliding sleeve disposing on the tubing string in the wellbore, the at least one second sliding sleeve having a second housing outlet associated with and having a pressure chamber, the at least one second sliding sleeve opening the second housing outlet in response to a pressure differential between the pressure chamber and fluid pressure communicated in the wellbore annulus by the first sliding sleeve, the at least one open second sliding sleeve passing fluid out the open second housing outlet and communicating fluid pressure from the tubing string to the wellbore annulus through the open second housing outlet associated with the at least one second sliding sleeve. 22. The apparatus of claim 21, further comprising at least one packing element disposing on the tubing string in the wellbore, the at least one packing element isolating the wellbore annulus around the first and second sliding sleeves from other portions of the wellbore. 23. The apparatus of claim 21, wherein the first sliding sleeve comprises: a movable sleeve being movable from a closed condition to an open condition relative to the first housing outlet; anda seat disposed on the movable sleeve and engaging with a plug when deployed down the tubing string,the movable sleeve moving to the open condition in response to fluid pressure applied against the seated plug. 24. The apparatus of claim 21, wherein the at least one second sliding sleeve disposes uphole of the first sliding sleeve on the tubing string. 25. The apparatus of claim 21, wherein the at least one second sliding sleeve comprises: a movable sleeve being movable from a closed condition to an open condition relative to the second housing outlet, the movable sleeve moving from the closed condition to the open condition in response to the pressure differential between the wellbore annulus and the pressure chamber, the movable sleeve in the open condition permitting fluid pressure from the tubing string to communicate to the wellbore annulus through the second housing outlet. 26. The apparatus of claim 25, wherein the pressure chamber is defined between the movable sleeve and a housing portion of the at least one second sliding sleeve. 27. The apparatus of claim 26, wherein the fluid pressure in the wellbore annulus acts against the movable sleeve. 28. The apparatus of claim 25, wherein the movable sleeve comprises an internal sleeve movably disposed in a bore of a housing of the at least one second sliding sleeve, the housing defining the second housing outlet. 29. The apparatus of claim 25, wherein the movable sleeve comprises an external sleeve movably disposed on a housing of the at least one second sliding sleeve, the housing defining the second housing outlet. 30. The apparatus of claim 21, further comprising at least one third sliding sleeve disposing on the tubing string in the wellbore, the at least one third sliding sleeve having a third housing outlet and having another pressure chamber, the at least one third sliding sleeve opening the third housing outlet in response to a same or different pressure differential between the wellbore annulus and the pressure chamber.
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