Inflatable packers and methods of utilization

• US 4,869,324 A
• Filed: 03/21/1988
• Issued: 09/26/1989
• Est. Priority Date: 03/21/1988
• Status: Expired due to Term

• Current Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Holder, Danny J.
• Primary Examiner(s): Neuder, William P.
• Application Number:
  US07/170,990
• Time in Patent Office: 554 Days
• Field of Search: 166/123, 166/124, 166/125, 166/187, 166/182, 166/186, 166/187, 166/191, 166/250, 166/373, 166/374, 166/387, 277/34, 277/34.3, 277/34.6
• US Class Current: 166/387
• CPC Class Codes: E21B 23/06 for setting packers
• CPC Class Codes: E21B 33/124 Units with longitudinally-spaced plugs for isolating the intermediate space
• CPC Class Codes: E21B 33/127 with inflatable sleeve E21B33/122, E21B33/124 take precedence

Abstract

Modifications are provided for both single unit and dual unit inflatable packers or bridge plugs permitting such inflatable tools to be inserted in a well through the primary tubing string which in turn is suitably sealably anchored in the well above the producing formations. The inflatable tool is inserted into the well on a conduit, such as coiled tubing, and fluid pressure transmitted through the conduit is utilized to effect the expansion and setting of the inflatable elements of the inflatable tool. The conduit is connected to the inflatable tool by a fluid pressure operated release mechanism and, following the inflation of the inflatable element or elements, the conduit may be utilized to supply treatment fluid or cementing fluid to a formation isolated by the inflatable tool. Alternatively, the conduit may be disconnected from the inflatable tool and retrieved from the well to permit the inflated tool to maintain a production formation in an isolated condition, to prevent further leakage of a leaking packer, or to permit wireline installation of a choke to regulate the amount of flow into or out of a producing or injection formation isolated by the inflated tool.

Claims

1. In a producing subterranean well traversing a plurality of production formations and having a tubing string extending from the well surface to a position above said production formations, the method of isolating and treating at least one of said production formations comprising the steps

detachably securing an inflatable packer to the end of a small diameter conduit by a run-in tool having a fluid pressure operated release mechanism;

said inflatable packer having an open central bore and a sleeve defining an upwardly facing ball seating surface shearably secured in said central bore;

running the inflatable packer on said conduit through said tubing string and said packer to a position above a selected production formation;

passing a ball through said coiled tubing to seat on said ball seat;

passing pressurized fluid through said conduit and into the inflatable packer to set the inflatable packer within the casing and isolate said selected production formation from upper formations;

increasing the fluid pressure in the said conduit to shearably force said sleeve and ball downwardly out of the inflated packer; and

supplying treatment fluid to said selected formation through said conduit.

2. The method of claim 1 further comprising the steps of:

releasing the inflatable packer from the end of the small diameter conduit by operating said fluid pressure operated release mechanism;

removing the small diameter conduit from the well;

engaging the inflatable packer by wireline to effect the deflation thereof and removal from the well.

3. In a producing subterranean well having a casing traversing a plurality of production formations and perforated to communicate with said formations, a packer sealably set in said casing above said production formations, and a tubing string sealably mounted in said packer and extending to the well surface, the method of isolating and treating at least one of said production formations comprising the steps of:

detachably securing an inflatable packer to the end of coiled tubing by a run-in tool having a fluid pressure operated release mechanism and an upwardly facing ball seating surface;

said inflatable packer having an open central bore and a sleeve defining an upwardly facing ball seating surface shearably secured in said central bore;

running the inflatable packer on said coiled tubing through said production tubing string and said production packer to a position above a selected production formation;

passing a ball through said coiled tubing to seat on said ball seat;

passing pressurized fluid through the coiled tubing and into the inflatable packer to set the inflatable packer within the casing and isolate said selected production formation from upper formations;

increasing the fluid pressure in the coiled tubing to shearably force said sleeve and ball downwardly to open said central bore of the inflated packer; and

supplying treatment fluid to said selected formation through said coiled tubing.

4. In a producing subterranean well having a casing traversing a plurality of production formations, one of which produces undesired fluid and others of which produce desired hydrocarbon fluids, and having tubing string suspended in the well and terminating above said production formations;

the method of isolating the undesired fluid producing formation comprising the steps of;

assembling two inflatable packers in sufficient axially spaced relationship to straddle said undesired fluid producing formation, said assembled inflatable packers having communicating central bores and inflation passages communicating with said central bores;

detachably securing the upper inflatable packer to the end of a small diameter conduit by a run-in tool having a fluid pressure operated release mechanism;

running the assembled inflatable packers on said conduit through said tubing string to position the two inflatable packers in straddling relationship to said undesired fluid producing formation; and

passing pressurized fluid through said conduit to set the inflatable packers within the well and isolate said undesirable fluid producing formation.

6. The method of claim 4 further comprising the steps of:

creating a fluid pressure within the bore of said tubular run-in tool to actuate said fluid pressure operated release mechanism and effect the release of said run-in tool from the upper inflatable packer; and

retrieving said conduit and said run-in tool from the well.

7. The method of claim 6 further comprising engaging the upper inflatable packer by wireline to first deflate and then retrieve both deflated packers from the well.

8. The method of claim 4 wherein said lower inflatable packer has a ball seat sleeve shearably secured in the bore thereof and said run-in tool has a larger ball seat formed therein;

said step of passing pressurized fluid to set said inflatable packers comprising first positioning a ball to seat on said ball seat sleeve;

after inflation of said inflatable packers, increasing the fluid pressure in said conduit to force said shearably secured ball seat sleeve downwardly to open said central bore of said lower inflatable packer;

passing a second ball through said conduit to seat on said larger ball seat in said run-in tool; and

increasing fluid pressure in said conduit sufficiently to actuate said pressure operated release mechanism, thereby permitting said conduit and run-in tool to be retrieved from the well.

5. In a producing subterranean well having a casing traversing a plurality of production formations, one of which produces undesired fluid and others of which produce desired hydrocarbon fluids;

a production packer sealably set in said casing above said production formations, and a production tubing string sealably mounted in said production packer, the method of isolating the undesired fluid producing formation comprising the steps of;

assembling two inflatable packers in sufficient axially spaced relationship to straddle said undesired fluid producing formation, said assembled inflatable packers having communicating central bores and inflation passages respectively communicating with said central bores;

detachably securing the upper inflatable packer to the end of coiled tubing by a tubular run-in tool having a fluid pressure operated release mechanism;

running the assembled inflatable packers on said conduit through said tubing string to position the two inflatable packers in straddling relationship to said undesired fluid producing formation; and

passing pressurized fluid through said conduit to set

the inflatable packers within the well and isolate said undesirable fluid producing formation.

9. In a producing subterranean well having a casing traversing a plurality of production formations, one of which produces undesired fluid, and others of which produce desired hydrocarbon fluids;

a production packer sealably set in said casing above said production formation, and a production tubing string sealably mounted in said production packer;

the method of isolating the undesired fluid producing formation comprising the steps of;

assembling two inflatable packers in sufficient axially spaced relationship to straddle said undesired fluid producing formation, said assembled inflatable packers having communicating central bores and inflation passages communicating with said central bores;

said lower packer having a ball seat sleeve shearably secured in the lower portion of said central bore;

detachably securing the upper inflatable packer to the end of coiled tubing by a fluid pressure operated release mechanism;

running the assembled inflatable packers on said coiled tubing through said production tubing string and said production packer to position the two inflatable packers in straddling relationship to said undesired fluid producing formation;

passing a ball through said coiled tubing to seat on said ball seat sleeve;

passing pressurized fluid through the coiled tubing to set the inflatable packers within the casing and isolate said undesirable fluid producing formation; and

increasing the fluid pressure in said coiled tubing to force said ball seat sleeve downwardly to open said central bore of said lower packer.

10. In a subterranean well having a casing traversing a production formation and perforated to communicate with said production formation, a packer set in said casing above said production formation but subject to leakage, and a tubing string sealably mounted in the bore of said packer and extending to the well surface, the method of preventing fluid leakage past said packer comprising the steps of:

assembling two inflatable packers in axially spaced relationship, said assembled inflatable packers having communicating central bores and inflation passages communicating with said central bores;

detachably securing the upper inflatable packer to the end of a small diameter conduit;

running the assembled inflatable packers on said conduit through said tubing string and said packer to position the lower inflatable packer in the casing below the packer and the upper inflatable packer in the bore of said packer; and

passing pressurized fluid through said coiled tubing to inflate said upper inflatable packer into sealing engagement with the bore of said production packer and to inflate said lower packer into sealing engagement with the casing, thereby preventing well fluids leaking past the production packer.

11. The method of claim 10 wherein the detachable securement of the upper inflatable packer to the small diameter conduit is accomplished by a run-in tool having a fluid pressure operated release mechanism and further comprising the step of increasing fluid pressure in said conduit sufficiently to actuate said pressure operated release mechanism, thereby permitting said conduit and run-in tool to be retrieved from the well.

12. The method of claim 11 wherein said lower inflatable packer has a ball seat sleeve shearably secured in the bore thereof and said run-in tool has a larger ball seat formed therein;

said step of passing pressurized fluid to set said inflatable packers comprising first passing a ball through said conduit to seat on said ball seat sleeve;

after inflation of said inflatable packers, increasing the fluid pressure in said conduit to force said shearably secured ball seat sleeve downwardly to open the center bore of said lower inflatable packer;

passing a second ball through said conduit to seat on said larger ball seat in said run-in tool; and

increasing fluid pressure in said conduit sufficiently to actuate said pressure operated release mechanism, thereby permitting said conduit and run-in tool to be retrieved from the well.

13. In a subterranean well having a casing traversing a plurality of production formations and perforated to communicate with said production formations, a packer sealably set in said casing, and a tubing string sealably mounted in said packer and extending to the well surface, the method of limiting fluid flow into or out of a selected production formation comprising the steps of:

detachably securing an inflatable packer to the end of a small diameter conduit by a run-in tool having a fluid pressure operated release mechanism;

said inflatable packer having an open central bore and a sleeve defining an upwardly facing ball seating surface shearably secured in said central bore;

running the inflatable packer on said conduit through said tubing string and said packer to a position above a selected production formation;

passing a ball through said conduit to seat on said ball seating surface;

passing pressurized fluid through said conduit and into the inflatable packer to set the inflatable packer within the casing and isolate said selected production formation from upper formations;

increasing the fluid pressure in said conduit to shearably force said sleeve and ball downwardly out of the central bore of the inflated packer, whereby fluid flow into or out of said selected formation passes through said central bore of said inflated packer;

disconnecting said run-in tool from the inflated packer and removing said conduit and run-in tool from the well;

running in a tubular flow controlling tool and detachably connecting same to the inflated packer in the position previously occupied by said run-in tool;

said flow control tool defining a constricted flow passage communicating between said central bore of said inflated packer and the bore of said tubing string, thereby limiting fluid flow into or out of said selected production formation.

14. The method of claim 13 including the step of releasably sealably securing a tubular choke defining said constricted flow passage within the bore of said tubular flow control tool, whereby said tubular choke is removable by wireline and replacable by another choke by wireline to permit variation in flow area of said constricted passage.

15. In an inflatable packer of the type suspended by coiled tubing and insertable through a tubing string for setting within a subterranean well by expansion of an inflatable element, said inflatable packer having a tubular body assembly defining a central bore extending downwardly through substantially the entire length of the inflatable packer, the improvement comprising:

radial port means disposed in said tubular body assembly below said inflatable element;

an elongated sleeve valve shearably positioned in said tubular body assembly in bridging relationship to said radial port means;

said sleeve valve extending upwardly through said tubular housing;

tubular connection means for connecting the top end of said tubular housing to said coiled tubing;

said tubular connection means surrounding and sealably engaged with the upper end of said sleeve valve and containing fluid pressure responsive means for disconnecting from said tubular body assembly;

whereby said coiled tubing and said tubular connection means may be removed from the well after setting said inflatable packer in the well; and

said sleeve valve having fishing tool engaging means on its said upper end, whereby said sleeve valve may be engaged by wireline for removal from the well, thereby equalizing fluid pressure above and below said inflatable element.

16. The apparatus of claim 15 wherein said tubular connection means has a radial fluid passage communicating between the bore of said tubular connection means and said fluid pressure responsive means;

and a sleeve in said tubular connection means defining an upwardly facing ball seat below said radial fluid passage;

said sleeve being sealingly engaged with said upper end of said sleeve valve.

17. The apparatus of claim 15 wherein the bottom end of said tubular housing comprises a tubular circulation housing having radial circulation ports;

a cylindrical valve element slidably and sealably mounted in the bore of said circulation housing and having radial passages alignable with said circulation ports in one axial position of said valve element relative to said circulation housing;

shearable means securing said cylindrical valve element in said one axial position;

means for connecting said sleeve valve in abutting relationship to said valve element; and

ball seat means secured to said sleeve valve for receiving a ball valve passed through said coiled tubing, whereby fluid pressure applied through said coiled tubing shifts said cylindrical valve element downwardly from said one position to a second position to close said circulation ports.

18. The apparatus of claim 17 further comprising means for locking said cylindrical valve element in said second position.

19. A run-in tool for running an inflatable packer having a tubular body into a subterranean well on coiled tubing comprising an upper tubular element secured to the bottom end of the coiled tubing;

a lower tubular element having its bottom end secured to the top portion of the tubular body of the inflatable packer and its top end inserted in the bottom end of said upper tubular element;

a latching collet on one of said tubular elements, a latching surface on the other of said tubular elements cooperating with said latching collet to releasably secure said upper and lower elements together;

a sleeve piston slidably and sealably mounted intermediate said upper and lower tubular elements;

said sleeve piston retaining said latching collet in engagement with said latching surface in one axial position of said sleeve piston;

shearable means for securing said sleeve piston in said one axial position;

fluid ports in said upper element communicating between one axial end of said sleeve piston and the bore of said upper tubular element; and

a ball valve seat in said upper tubular element for receiving a ball to close the bore of said upper tubular element below said ports, whereby fluid pressure may be applied through said coiled tubing to shift said sleeve piston from said one axial position to release said latching collet from said latching surface and permit retrieval of said upper tubular element, said piston and the ball from the well.

20. In a subterranean well having a casing traversing a plurality of production formations and perforated to communicate with said production formations, a packer sealably set in said casing, and a tubing string sealably mounted in said packer and extending to the well surface, the method of cementing the lower production formations without removal or contamination of the tubing string and packer, comprising the steps of:

detachably securing an inflatable packer to the end of a small diameter conduit by a run-in tool;

said inflatable packer having an open central bore and a sleeve defining an upwardly facing ball seating surface shearably secured in said central bore;

running the inflatable packer on said conduit through said tubing string and said packer to a position above a selected production formation;

passing a ball through said conduit to seat on said ball seating surface;

passing pressurized fluid through said conduit and into the inflatable packer to set the inflatable packer within the casing and isolate said selected production formation from upper formations;

increasing the fluid pressure in said conduit to shearably force said sleeve and ball downwardly out of said central bore of the inflated packer;

supplying cementing fluid to said lower production formation through said conduit; and

detaching said run-in tool from said inflated packer for retrieval from the well by said conduit.

21. In a subterranean well having a casing traversing a plurality of production formations and perforated to communicate with said production formations, a packer sealably set in said casing, and a tubing string sealably mounted in said packer and extending to the well surface, the method of cementing the lower production formations without removal or contamination of the tubing string and packer, comprising the steps of:

detachably securing an inflatable packer to the end of a small diameter conduit by a run-in tool having a fluid pressure operated release mechanism and an upwardly facing ball seat;

said inflatable packer having an open central bore and a sleeve defining an upwardly facing ball seating surface shearably secured in said central bore;

running the inflatable packer on said conduit through said tubing string and said packer to a position above a selected production formation;

passing a ball through said conduit to seat on said ball seating surface;

passing pressurized fluid through said conduit and into the inflatable packer to set the inflatable packer within the casing and isolate said selected production formation from upper formations;

increasing the fluid pressure in said conduit to shearably force said sleeve and ball downwardly out of said central bore of the inflated packer;

supplying cementing fluid to said lower production formation through said conduit;

passing a second ball through said conduit on said upwardly facing ball seat; and

increasing fluid pressure in said conduit to detach said run-in tool from said inflated packer for retrieval from the well by said conduit.

22. In a subterranean well having a casing traversing a plurality of production formations and perforated to communicate with said production formations, a packer sealably set in said casing, and a tubing string sealably mounted in said packer and extending to the well surface, the method of isolating and treating at least one of said production formations comprising the steps of:

detachably securing a tubular tool having an inflatable packing element to the end of a small diameter conduit by a tubular run-in tool having a fluid pressure operated release mechanism, said tubular tool having a normally open bore;

running the tool, with the inflatable element deflated, on said conduit through said tubing string and said packer to a position above a selected production formation;

passing pressurized fluid through the conduit and into said tool to expand the inflatable element into sealing engagement with the casing; and

utilizing said normally open bore of said tool to supply fluid to or remove fluid from said selected formation.

23. The method of claim 22 further comprising the step of temporarily closing said normally open bore of said tool to increase the fluid pressure in said conduit to a level sufficient to expand the inflatable elements.

24. The method of claim 22 wherein chemical treatment fluid is supplied to the selected formation through said conduit.

25. The method of claim 22 wherein cementing fluid is supplied to the selected formation through said conduit.

26. The method of claim 22 further comprising the step of regulating the rate of fluid flow into or out of said selected production formation by replacing said tubular run-in tool with a choke limiting the fluid flow passage area through said tubular tool.