Well treatment

• US 9,631,468 B2
• Filed: 09/03/2013
• Issued: 04/25/2017
• Est. Priority Date: 09/03/2013
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Miller, Matthew J.
• Primary Examiner(s): Bates, Zakiya W
• Application Number:
  US14/016,571
• Publication Number:
  US 20150060063A1
• Time in Patent Office: 1,330 Days
• CPC Class Codes: E21B 33/13 Methods or devices for cementing, for plugging holes, crevices or the like
• CPC Class Codes: E21B 34/142 unsupported or free-falling elements, e.g. balls, plugs, darts or pistons
• CPC Class Codes: E21B 43/26 by forming crevices or fractures
• CPC Class Codes: E21B 43/267 reinforcing fractures by propping

Abstract

In situ channelization treatment fluids are used in a multistage well treatment. Also, methods, fluids, equipment and/or systems relating to in situ channelization treatment fluids are used for treating a subterranean formation penetrated by a wellbore.

Claims

1. A method, comprising:

placing a downhole completion staging system tool in a wellbore adjacent a subterranean formation;

operating the downhole completion staging system tool to establish one or more passages for fluid communication between the wellbore and the subterranean formation in a plurality of wellbore stages spaced along the wellbore;

isolating one of the wellbore stages for treatment;

injecting an in situ channelization treatment fluid through the wellbore and the one or more passages of the isolated wellbore stage into the subterranean formation to form within a fracture a homogeneous region of continuously uniform distribution of solid particulates and thereafter aggregate the solid particulates to place clusters in the fracture; and

repeating the isolation and clusters placement for one or more additional stages

wherein the in situ channelization treatment fluid comprises a viscosified carrier fluid, the solid particulates, a breaker, and at least an anchorant, the breaker inducing settling of the solid particulates prior to closure of the fracture.

2. The method of claim 1, wherein the placement of the downhole completion staging system tool is tethered to a string.

3. The method of claim 1, wherein the downhole completion staging system tool is translated within the wellbore using the in situ channelization treatment fluid as a transport medium.

4. The method of claim 1, wherein the downhole completion staging system tool comprises a wireline tool string comprising a blanking plug and perforating guns, and further comprising setting the blanking plug in the wellbore, placing one or more perforation clusters above the blanking plug, and recovering the wireline tool string to the surface, wherein the in situ channelization treatment fluid is circulated through the wellbore into the formation to create the fracture, place the clusters or a combination thereof.

5. The method of claim 1, wherein the downhole completion staging system tool comprises a pipe or coiled tubing string comprising a jetting assembly, and further comprising placing the jetting assembly in the wellbore, closing an annulus around the string, circulating abrasive materials down the string through the jetting assembly to perforate a wellbore casing, wherein the in situ channelization treatment fluid is circulated through the annulus, perforations and into the formation to create the fracture, place the clusters or a combination thereof.

6. The method of claim 1, further comprising placing a production liner in the wellbore wherein the production liner is fitted with a plurality of sliding sleeves in the closed position, and inserting a sleeve-shifting device into a capture feature on the downhole completion staging system tool to open a fracturing port, wherein the in situ channelization treatment fluid is circulated through the fracturing port and into the formation to create the fracture, place the clusters or a combination thereof.

7. The method of claim 1, further comprising forming a plug between at least two stages.

8. The method of claim 7, wherein the plug is formed from an in situ channelization treatment fluid and further comprising re-slurrying the plug following completion of the clusters placement for one stage to access another one of the one or more additional stages for a subsequent isolation and clusters placement for the additional one of the one or more stages.

9. The method of claim 1, wherein in situ channelization treatment fluid from one stage is circulated in the wellbore to another stage to create the fracture, place the clusters or a combination thereof.

10. The method of claim 1, further comprising circulating another in situ channelization treatment fluid through the wellbore between stages to flush debris from the wellbore following completion of one stage and prior to initiation of a serial stage, wherein the flushing slurry treatment fluid may be the same or different treatment fluid with respect to the proppant placement treatment fluid of either or both of the immediately preceding or immediately subsequent stages.

11. The method of claim 1, wherein the solid particulates and the anchorant have different shapes, sizes, densities or a combination thereof.

12. The method of claim 1, wherein the anchorant is a fiber, a flake, a ribbon, a platelet, a rod, or a combination thereof.

13. The method of claim 12, wherein the anchorant is selected from the group consisting of polylactic acid, polyester, polycaprolactam, polyamide, polyglycolic acid, polyterephthalate, cellulose, wool, basalt, glass, rubber, sticky fiber, or a combination thereof.

14. The method of claim 1, wherein after injecting the in situ channelization treatment fluid, said fluid is allowed to settle in the fracture for a period of time.

15. A method, comprising:

placing a downhole completion staging tool in a wellbore adjacent a subterranean formation;

operating the downhole completion staging tool to establish one or more passages for fluid communication between the wellbore and the subterranean formation in a plurality of wellbore stages spaced along the wellbore;

isolating one or more of the wellbore stages for treatment;

injecting an in situ channelization treatment fluid through the wellbore and the one or more passages of the isolated wellbore stage into the subterranean formation to form within a fracture a homogeneous region of continuously uniform distribution of solid particulates and thereafter aggregate the solid particulates to place clusters in the fracture;

circulating an in situ channelization treatment fluid through the isolated wellbore stage to facilitate removal of proppant from the wellbore stage; and

repeating the isolation, clusters placement and slurry treatment fluid circulation for one or more additional stages

wherein the in situ channelization treatment fluid comprises a carrier fluid, the solid particulates, a breaker, and at least an anchorant, the breaker inducing settling of the solid particulates prior to closure of the fracture.

16. The method of claim 15, further comprising reducing the viscosity of the in situ channelization treatment fluid after its placement.

17. The method of claim 15, wherein the viscosity reduction is enabled by a breaker.

18. A method, comprising:

placing a downhole completion staging tool in a wellbore adjacent a subterranean formation;

operating the downhole completion staging tool to establish one or more passages for fluid communication between the wellbore and the subterranean formation in a plurality of wellbore stages spaced along the wellbore;

injecting an in situ channelization treatment fluid through the wellbore and the one or more passages into the subterranean formation to form within a fracture a homogeneous region of continuously uniform distribution of solid particulates and a breaker, and thereafter aggregate the at least one solid particulates to place clusters in the fracture;

wherein the breaker induces settling of the at least one solid particulate in the fracture prior to closure of the fracture;

moving the downhole completion staging tool away from the one or more passages either before, during or after the injection without removing the downhole completion staging tool from the wellbore;

deploying a diversion agent to block further flow through the one or more passages;

circulating an in situ channelization treatment fluid through the wellbore as the injected treatment fluid or as a flush to facilitate removal of proppant from the wellbore; and

repeating the downhole completion staging tool placement and operation, clusters placement, downhole completion staging tool movement and in situ channelization treatment fluid circulation for one or more additional stages.