Determining and tracking downhole particulate deposition

• US 7,316,272 B2
• Filed: 07/22/2005
• Issued: 01/08/2008
• Est. Priority Date: 07/22/2005
• Status: Expired due to Fees

• Current Assignee: Schlumberger Technology Corporation (SLB)
• Original Assignee: Schlumberger Technology Corporation (SLB)
• Inventors: Monsegue, Alan, Lorde, Juliet, Hurst, Gary D.
• Primary Examiner(s): Gay; Jennifer H.
• Assistant Examiner(s): DITRANI, ANGELA M
• Application Number:
  US11/161,099
• Publication Number:
  US 20070017673A1
• Time in Patent Office: 900 Days
• Field of Search: None
• US Class Current: 166/255.1
• CPC Class Codes: E21B 43/04 Gravelling of wells
• CPC Class Codes: E21B 47/10 Locating fluid leaks, intrusions or movements

Abstract

Methods and apparatus provide for the characterization of injected fluid flow within a wellbore. Particular embodiments include injecting a slurry comprising a particulate material and a carrier fluid into an isolated wellbore annulus and acquiring composite density readings at one or more discrete locations along the annulus while depositing the particulate material. Interpreting the acquired composite density readings provides an evaluation of the placement of the deposited particulate material within the isolated wellbore annulus. A further step may include determining when the slurry reaches each of the discrete locations as indicated by increases in the composite density reading at each of the discrete locations and furthermore, acquiring a maximum composite density reading at each of the discrete locations along the tubular member as an indication of the quantity of deposited particulate material at each of the discrete locations. Apparatus includes a plurality of densimeters secured at discrete axial locations within a tubular member for acquiring composite density readings within an isolated wellbore annulus.

Claims

1. A method for depositing particulate material within a wellbore, the method comprising the steps of:

isolating a wellbore annulus defined by a tubular member disposed in the wellbore;

coupling a plurality of densimeters to the tubular member to remain with the tubular member;

injecting a slurry comprising a particulate material and a carrier fluid into the isolated wellbore annulus;

depositing the particulate material from the slurry into the isolated wellbore annulus;

acquiring composite density readings with the plurality of densimeters at a plurality of discrete locations along the tubular member during the step of depositing the particulate material; and

interpreting the acquired composite density readings to evaluate placement of the deposited particulate material within the isolated wellbore annulus.

2. The method of claim 1, further comprising the step of:

determining when the slurry reaches each of the discrete locations as indicated by increases in the composite density reading at each of the discrete locations.

3. The method of claim 1, further comprising the step of:

acquiring a maximum composite density reading at each of the discrete locations along the tubular member, wherein the maximum composite density reading provides an indication of the quantity of deposited particulate material at each of the discrete locations.

4. The method of claim 1, wherein the isolated wellbore annulus is in a deviated section of the wellbore and the composite density readings are acquired by the plurality of densimeters, the method further comprising the step of:

placing a first of the plurality of densimeters adjacent to a heel of the isolated wellbore annulus and placing a second densimeter adjacent to a toe of the isolated wellbore annulus.

5. The method of claim 4, further comprising the step of:

determining when the slurry reaches the isolated wellbore as indicated by increases in the composite density reading of the first densimeter.

6. The method of claim 4, further comprising the step of:

determining a particulate concentration in the slurry as indicated by increases in the composite density reading of the first densimeter.

7. The method of claim 4, further comprising the step of:

determining when the slurry reaches a toe of the isolated wellbore as indicated by increases in the composite density reading of the second densimeter.

8. The method of claim 4, further comprising the step of:

characterizing at least one of the alpha wave and beta wave during a gravel packing operation.

9. The method of claim 1, further comprising the step of:

monitoring the acquired composite density readings in real time or near real time.

10. The method of claim 1, further comprising the steps of:

placing the tubular member into the wellbore;

obtaining positioning composite density readings simultaneously while placing the tubular member into the wellbore;

correlating the positioning composite density readings to locations along the isolated wellbore annulus, wherein the positioning composite density readings represent zero readings of the composite density along the wellbore annulus.

11. The method of claim 10, wherein the positioning composite density readings are obtained from a densimeter positioned inside the tubular member at or near an end thereof.

12. The method of claim 1, further comprising the steps of:

removing the tubular member from the wellbore;

obtaining removal composite density readings simultaneously with removing the tubular member from the wellbore;

correlating the removal composite density readings to locations along the isolated wellbore annulus, wherein the removal composite density readings provide an indication of the quantity of deposited particulate material along the isolated wellbore annulus.

13. The method of claim 1, wherein the particulate material is selected from gravel, proppants or combinations thereof.

14. The method of claim 13, wherein the particulate material is gravel and the deposition of the gravel provides a gravel pack within the isolated wellbore annulus.

15. The method of claim 1, wherein a portion of the wellbore defining the isolated wellbore annulus is open-hole.

16. The method of claim 1, wherein a portion of the wellbore defining the isolated wellbore annulus has casing cemented therein with perforations formed through the casing and cement.

17. The method of claim 1, further comprising:

creating one or more fractures in the isolated wellbore annulus prior to or while carrying out the step of injecting the slurry.

18. The method of claim 17, further comprising:

depositing the particulate material into the one or more fractures.

19. The method of claim 1, wherein the plurality of densimeters are nuclear densimeters positioned at discrete locations.

20. A method for characterizing fluid flow within a wellbore, the method comprising the steps of:

isolating a wellbore annulus defined by a tubular member disposed in a deviated section of the wellbore;

a fluid into the isolated wellbore annulus;

acquiring composite density readings at one or more discrete locations along the tubular member during the step of injecting the fluid; and

interpreting the acquired composite density readings to characterize the flow of the injected fluid within the isolated wellbore annulus.

21. The method of claim 20, wherein the acquired composite density readings are interpreted to determine the flow rate of the fluid within the wellbore.