Use of sensors coated with elastomer for subterranean operations

• US 9,200,500 B2
• Filed: 10/30/2012
• Issued: 12/01/2015
• 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: Roddy, Craig W., Covington, Ricky L.
• Primary Examiner(s): Thompson, Kenneth L
• Application Number:
  US13/664,286
• Publication Number:
  US 20130062068A1
• Time in Patent Office: 1,127 Days
• Field of Search: 166/66, 166/65.1, 166/255.1, 166/250.1, 166/305.1
• US Class Current: 1/1
• 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 47/01 Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
• 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 comprising placing a composition comprising a wellbore servicing fluid and a Micro-Electro-Mechanical System (MEMS) sensor in a subterranean formation, whereby the MEMS sensor is coated with an elastomer. The elastomer-coated MEMS sensor is used to detect one or more parameters, including a compression or swelling of the elastomer, an expansion of the elastomer, or a change in density of the composition.

Claims

1. A method comprising:

placing a wellbore servicing composition comprising a plurality of elastomer-coated sensors in a wellbore, a subterranean formation, or both; and

using the elastomer-coated sensors to detect one or more parameters, wherein the one or more parameters includes a change in the elastomer.

2. The method of claim 1 wherein the change in the elastomer comprises a compression of the elastomer.

3. The method of claim 1 wherein the change in the elastomer comprises an expansion or swelling of the elastomer.

4. The method of claim 1 wherein the wellbore servicing composition is formulated as a drilling fluid, a spacer fluid, a sealant, a fracturing fluid, a gravel pack fluid, or a completion fluid.

5. The method of claim 1 wherein the wellbore servicing composition is a sealant, the method further comprising the step of allowing the sealant to set.

6. The method of claim 1 wherein the elastomer-coated sensors comprise a Micro-Electro-Mechanical System (MEMS) sensor, a liquid crystal display (LCD) sensor, a conductive polymer sensor, a bio-polymer sensor, or combinations thereof.

7. The method of claim 1 wherein the composition is placed in a CO2 injection, storage, or disposal well.

8. The method of claim 1 further comprising the step of using an interrogator to communicate with the elastomer-coated sensors.

9. The method of claim 1 wherein the wellbore servicing composition comprises a plurality of elastomer-coated MEMS sensors in an amount from about 0.001 to about 10 weight percent of the composition, wherein the plurality of elastomer-coated MEMS sensors are approximately 0.01 mm² to approximately 10 mm² in size.

10. The method of claim 1 wherein the one or more parameters further comprises a change in the wellbore servicing composition.

20. The method of claim 10 wherein the change in the wellbore servicing composition comprises a change in a density of the composition.

11. A wellbore servicing composition comprising:

a base fluid; and

a plurality of elastomer-coated sensors, wherein each of the plurality of elastomer-coated sensors is configured to detect one or more parameters, the one or more parameters including a change in the elastomer.

12. The composition of claim 11 wherein the sensors comprise, a Micro-Electro-Mechanical System (MEMS) sensor, an LCD sensor, a conductive polymer sensor, a bio-polymer sensor, or combinations thereof.

13. The composition of claim 11 wherein the elastomer-coated sensors are approximately 0.01 mm² to approximately 10 mm² in size, wherein the elastomer-coated sensors comprise an amount from about 0.001 to about 10 weight percent of the composition.

14. The composition of claim 11 wherein the elastomer has a specific gravity in the range of about 0.05 to about 2.00, relative to water.

15. The composition of claim 11 wherein the elastomer comprises a copolymer of styrene and divinylbenzene;

a copolymer of methylmethacrylate and acrylonitrile;

a copolymer of styrene and acrylonitrile;

a terpolymer of methylmethacrylate, acrylonitrile, and vinylidene dichloride;

a terpolymer of styrene, vinylidene chloride, and acrylonitrile;

a phenolic resin;

polystyrene;

a WellLife®

material;

or combinations thereof.

16. The composition of claim 11 wherein the sensors detect a change in a density of the composition upon a compression or expansion of the elastomer.

17. The composition of claim 11 wherein the change in the elastomer comprises a compression of the elastomer.

18. The composition of claim 11 wherein the change in the elastomer comprises an expansion or swelling of the elastomer.

19. The composition of claim 11 wherein the wellbore servicing composition is formulated as a drilling fluid, a spacer fluid, a sealant, a fracturing fluid, a gravel pack fluid, or a completion fluid.