Mitigating annular pressure buildup using temperature-activated polymeric particulates

Patent metadata

Field	Value
Publication number	US-9631132-B2
Application number	US-201313939581-A
Country	US
Kind code	B2
Filing date	Jul 11, 2013
Priority date	Jul 11, 2013
Publication date	Apr 25, 2017
Grant date	Apr 25, 2017

Abstract

A variety of methods and compositions, including, in one embodiment, a method that comprises providing a treatment fluid comprising a carrier fluid and temperature-activated polymeric particulates. The temperature-activated polymeric particulates may include a compressible gas trapped in the temperature-activated polymeric particulates. The method may further comprise introducing the treatment fluid into a well bore annulus.

First claim

What is claimed is:

1. A method of servicing a well bore comprising:
providing a treatment fluid comprising a carrier fluid and temperature-activated polymeric particulates, wherein the temperature-activated polymeric particulates comprise at least one polymeric material selected from the group consisting of polystyrene, styrene-butadiene copolymers, polyfluorostyrene, polychlorostyrene, polydichlorostyrene, and polybromostyrene; and
introducing the treatment fluid into a well bore annulus, wherein the temperature activated particulates have a selected glass transition temperature and wall thickness such that the temperature activated particulates withstand an initial temperature and pressure during an initial placement of the temperature-activated particulates into the well bore annulus such that the temperature-activated particulates maintain at least about 95% of their initial volume during the initial placement, wherein the initial volume is the volume of the temperature-activated particulates prior to the introducing; wherein the wall thickness is in a range from about 100 microns to about 1 millimeter.

2. The method of claim 1 , wherein the treatment fluid is used to displace a drilling fluid from the well bore annulus.

3. The method of claim 2 , further comprising introducing a cement composition into the well bore annulus, wherein the treatment fluid separates the cement composition from the drilling fluid.

4. The method of claim 1 , wherein at least a portion of the temperature-activated polymer particulates reduces in volume to affect annular pressure in response to a compressive force due to a temperature increase in the well bore annulus.

5. The method of claim 4 , wherein the temperature increase is to a temperature of about 200° F. or greater.

6. The method of claim 4 , wherein the at least a portion of the temperature-activated polymeric particulates rebound after release of the compressive force to at least about 50% of the initial volume.

7. The method of claim 1 , further comprising allowing at least a portion of the treatment fluid to become trapped in the well bore annulus.

8. The method of claim 1 , wherein the temperature-activated polymeric particulates have a glass transition temperature in a range of from about 200° F. to about 600° F.

9. The method of claim 1 , wherein the temperature-activated polymeric particulates comprise an exterior shell and an interior volume, wherein a compressible gas is trapped in the interior volume.

10. The method of claim 1 , wherein the temperature-activated particulates comprise fiber-reinforced particulates.

11. The method of claim 1 , wherein the temperature-activated polymeric particulates are present in the treatment fluid in an amount in a range of from about 1% to about 50% by volume of the treatment fluid.

12. The method of claim 1 wherein the glass transition temperature of the temperature-activated particulates is within 10° F. or less of a bottomhole circulating temperature during production.

13. A method of servicing a well bore comprising:
selecting temperature-activated polymeric particulates based on a bottom hole circulating temperature of the well bore;
providing a treatment fluid comprising a carrier fluid and the temperature-activated polymeric particulates having an initial volume, wherein the temperature-activated polymeric particulates comprise an exterior shell and an interior volume, wherein a compressible gas is trapped in the interior volume; and
introducing the treatment fluid into a well bore annulus, wherein the temperature-activated polymeric particulates have a selected glass transition temperature and wall thickness such that the temperature activated particulates withstand an initial temperature and pressure during an initial placement of the temperature-activated particulates into the well bore annulus such that the temperature-activated particulates maintain at least about 95% of their initial volume during the initial placement, wherein the initial volume is the volume of the temperature-activated particulates prior to the introducing; wherein the wall thickness is in a range from about 100 microns to about 1 millimeter;
wherein the temperature-activated particulates are temperature activated such that temperature rises that are above the glass transition temperature and occur after the initial placement activate the temperature-activated particulates such that compressive forces will then cause the temperature-activates particulates to reduce in volume.

14. The method of claim 13 , further comprising:
using the treatment fluid to displace a drilling fluid from the well bore annulus;
introducing a cement composition into the well bore annulus, wherein the treatment fluid separates the cement composition from the drilling fluid; and
allowing at least a portion of the treatment fluid to become trapped in the well bore annulus.

15. The method of claim 13 , wherein at least a portion of the temperature-activated polymer particulates reduces in volume to affect annular pressure in response to a compressive force due to a temperature increase in the well bore annulus.

16. The method of claim 13 , wherein the glass transition temperature of the temperature-activated polymeric particulates is in a range of from about 200° F. to about 600° F., and wherein the temperature-activated polymeric particulates comprise at least one polymeric material selected from the group consisting of polystyrene, styrene-butadiene copolymers, polyfluorostyrene, polychlorostyrene, polydichlorostyrene, polybromostyrene, polypropylene, polypropylene oxide, polyp-phenylene terephthalamide, polyacrylamide, polycyclohexylacrylamide, polyisopropyl acrylamide, poly2-tert-butylacrylamide, polymethyl methacrylate, polyacrylate, polycyclohexyl acrylate, polybutyl acrylate, polyacrylic acid, polybenzyl methacrylate, polytrimethylsilyl methacrylate, polydiethylaminoethyl methacrylate, polyvinyl acetate, polyvinyl acetal, polythio-1,4-phenylene, polyvinyl ferrocene, polyvinyl pyridine, polyvinyl pyrrolidone, polyvinyl trifluoroacetate, nylon, polyacrylonitrile, polyacetoxystyrene, polyacenaphthylene, polybutadiene, polylactone, polybutyl vinyl ether, cellulose, cellulose nitrate, polychloroethylene, polychlorofluoroethylene, polyphenyl vinyl ketone, polyethylene, and polyethylcellulose.

17. The method of claim 13 wherein the glass transition temperature of the temperature-activated particulates is within 10° F. or less of a bottomhole circulating temperature during production.

18. The method of claim 13 , wherein the temperature-activated particulates are selected to have a glass transition temperature that is higher than bottom hole circulating temperature during placement and within about 10° F. or less of bottom hole circulating temperature during production.

19. A well treating system comprising:
a treatment fluid comprising:
a carrier fluid; and
temperature-activated polymeric particulates having an initial volume and a glass transition temperature in a range of from about 200° F. to about 600° F., wherein the temperature-activated polymeric particulates comprise at least one polymeric material selected from the group consisting of polystyrene, styrene-butadiene copolymers, polyfluorostyrene, polychlorostyrene, polydichlorostyrene, and polybromostyrene; wherein the temperature-activated polymeric particulates have a selected glass transition temperature and wall thickness such that the temperature activated particulates withstand an initial temperature and pressure during an initial pl

Assignees

• Halliburton Energy Services Inc

Inventors

• Ravi Krishna M
• Guillory Brittney N
• Boul Peter James
• Santra Ashok K

Classifications

• C09K8/035

  Organic additives · CPC title

• C09K8/40 Primary

  Spacer compositions, e.g. compositions used to separate well-drilling from cementing masses · CPC title

• C09K8/02 Primary

  Well-drilling compositions · CPC title

• C08L25/06

  Polystyrene · CPC title