Use of Micro-Electro-Mechanical Systems (MEMS) in Well Treatments

• US 20110192594A1
• Filed: 02/21/2011
• Published: 08/11/2011
• Est. Priority Date: 04/02/2007
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Ravi, Krishna M., RODDY, Craig W., Frisch, Gary, Bonavides, Clovis
• Granted Patent: US 8,297,352 B2
• Time in Patent Office: Days
• US Class Current: 166/250.01
• CPC Class Codes: E21B 33/13 Methods or devices for cementing, for plugging holes, crevices or the like
• CPC Class Codes: E21B 43/25 Methods for stimulating production by vibrating earth formations E21B43/003
• CPC Class Codes: E21B 47/005 Monitoring or checking of cementation quality or level
• CPC Class Codes: E21B 47/10 Locating fluid leaks, intrusions or movements
• CPC Class Codes: E21B 47/13 by electromagnetic energy, e.g. radio frequency

Abstract

A method of servicing a wellbore, comprising placing a plurality of Micro-Electro-Mechanical System (MEMS) sensors in a wellbore composition, flowing the wellbore composition in the wellbore, and determining one or more fluid flow properties or characteristics of the wellbore composition from data provided by the MEMS sensors during the flowing of the wellbore composition. A method of servicing a wellbore, comprising placing a plurality of Micro-Electro-Mechanical System (MEMS) sensors in at least a portion of a spacer fluid, a sealant composition, or both, pumping the spacer fluid followed by the sealant composition into the wellbore, and determining one or more fluid flow properties or characteristics of the spacer fluid and/or the cement composition from data provided by the MEMS sensors during the pumping of the spacer fluid and sealant composition into the wellbore.

Claims

1. A method of servicing a wellbore, comprising:

placing a plurality of Micro-Electro-Mechanical System (MEMS) sensors in a wellbore composition;

flowing the wellbore composition in the wellbore; and

determining one or more fluid flow properties or characteristics of the wellbore composition from data provided by the MEMS sensors during the flowing of the wellbore composition.

2. The method of claim 1, wherein the fluid flow properties or characteristics include an indication of laminar and/or turbulent flow of the wellbore composition.

3. The method of claim 1, wherein the fluid flow properties or characteristics include velocity and/or flow rate of the wellbore composition.

4. The method of claim 1, wherein the wellbore composition is circulated in the wellbore and a fluid flow profile is determined over at least a portion of the length of the wellbore.

5. The method of claim 4, further comprising comparing the fluid flow profile to a theoretical or design standard for the fluid flow profile.

6. The method of claim 5, wherein the comparing is carried out in real-time during the servicing of the wellbore.

7. The method of claim 6, further comprising altering or adjusting one or more operational parameters of the servicing of the wellbore in response to the comparing in real time.

8. The method of claim 7, wherein the altering or adjusting is effective to change a condition of the wellbore.

9. The method of claim 8, wherein the condition of the wellbore is a build up of material on an interior of the wellbore and the altering or adjusting includes remedial action to reduce an amount of the build up.

10. The method of claim 9, wherein the wellbore composition is a drilling fluid and the build up is a gelled mud or filter cake.

11. The method of claim 10, wherein the wellbore is treated to remove at least a portion of the build up.

12. The method of claim 11, wherein the treatment to remove at least a portion of the build up comprises changing a flow rate of the wellbore composition, changing a characteristic of the wellbore composition, placing an additional composition in the wellbore to react with the build up or change a characteristic of the buildup, moving a conduit within the wellbore, placing a tool downhole to physically contact and removing the build up, or any combination thereof.

13. The method of claim 1, wherein the fluid flow property or characteristic is an actual time of arrival of at least a portion of the wellbore composition comprising the MEMS sensors.

14. The method of claim 13, wherein the actual time of arrival is compared to an expected time of arrival to determine a condition of the wellbore.

15. The method of claim 14, wherein where the actual time of arrival is before the expected time of arrival indicates a decreased flow path through the wellbore.

16. The method of claim 15, wherein the decreased flow path through the wellbore is attributable at least in part to a build up of gelled mud or filter cake on an interior of the wellbore.

17. The method of claim 4, wherein the flow profile identifies a location of one or more areas of restricted flow in the wellbore.

18. The method of claim 17, further comprising comparing the location of one or more areas of restricted flow in the wellbore to a theoretical or design standard for the wellbore.

19. The method of claim 18, wherein the one or more areas of restricted fluid flow correspond to an expected location of a downhole tool or component based upon the theoretical or design standard for the wellbore.

20. The method of claim 19, wherein the downhole tool or component is a casing collar, centralizer, or spacer.

21. A method of servicing a wellbore, comprising:

placing a plurality of Micro-Electro-Mechanical System (MEMS) sensors in at least a portion of a spacer fluid, a sealant composition, or both;

pumping the spacer fluid followed by the sealant composition into the wellbore; and

determining one or more fluid flow properties or characteristics of the spacer fluid and/or the cement composition from data provided by the MEMS sensors during the pumping of the spacer fluid and sealant composition into the wellbore.

22. The method of claim 21, wherein the wellbore comprises a casing forming an annulus with the wellbore wall, wherein the sealant composition is a cement slurry, and wherein the cement slurry is pumped down the annulus in a reverse cementing service.

23. The method of claim 22, further halting the pumping of the cement slurry in the wellbore in response to detection of MEMS sensors at a given location in the wellbore.

24. The method of claim 23, further comprising monitoring the wellbore for movement of the MEMS sensors after the halting of the pumping.

25. The method of claim 24, further comprising signaling an operator upon detection of movement of the MEMS sensors after the halting of the pumping.

26. The method of claim 25, further comprising activating at least one device to prevent flow out of the well upon detection of movement of the MEMS sensors after the halting of the pumping.