Enhanced acid soluble wellbore strengthening solution

Patent metadata

Field	Value
Publication number	US-10093845-B2
Application number	US-201314412642-A
Country	US
Kind code	B2
Filing date	Jul 1, 2013
Priority date	Jul 2, 2012
Publication date	Oct 9, 2018
Grant date	Oct 9, 2018

Abstract

Wellbore fluid compositions containing a base fluid; at least one synthetic fiber; and a particulate solid; where one or more of the at least one synthetic fiber and the particulate solid are completely or substantially acid soluble are provided. In another aspect, methods of reducing loss of wellbore fluid in a wellbore to a formation are provided, including: introducing into the wellbore a fluid composition comprising one or more synthetic fibers and one or more particulate solids.

First claim

What is claimed:

1. A wellbore fluid composition comprising:
a base fluid;
at least one synthetic fiber; and
a particulate solid;
wherein one or more of the at least one synthetic fiber and the particulate solid are completely or substantially acid soluble, and
wherein the at least one synthetic fiber is added to the wellbore fluid composition at 0.25 wt % to 3 wt % of the weight of the added particulate solid;
wherein the wellbore fluid composition contains substantially no synthetic fiber having a length equal to or more than 8 mm; and
wherein the at least one synthetic fiber has a denier of at least 2.

2. The wellbore fluid composition of claim 1 , wherein the base fluid comprises an oleaginous fluid.

3. The wellbore fluid composition of claim 1 , wherein the base fluid comprises a non-oleaginous fluid.

4. The wellbore fluid composition of claim 1 , wherein the at least one synthetic fiber has a length within the range of 4 mm to 7 mm.

5. The wellbore fluid composition of claim 1 , wherein the at least one synthetic fiber has a length within the range of 5 mm to 6 mm.

6. The wellbore fluid composition of claim 1 wherein the particulate solid added to the wellbore fluid composition ranges from 5 ppb to 100 ppb.

7. The wellbore fluid composition of claim 1 , wherein the particulate solid is calcium carbonate.

8. The wellbore fluid composition of claim 1 , wherein the at least one synthetic fiber is nylon.

9. The wellbore fluid composition of claim 1 , wherein the at least one synthetic fiber is selected from a group consisting of nylon, polyesters, polyethylene terephthalate, polytriphenylene terephthalate, polybutylene terephthalate has a diameter within the range of 5 microns to 15 microns.

10. The wellbore fluid composition of claim 1 , wherein the at least one synthetic fiber has a denier of at least 4.

11. The wellbore fluid composition of claim 1 , wherein the at least one synthetic fiber has a denier of at least 6.

12. The wellbore fluid composition of claim 1 , wherein the at least one synthetic fiber has a denier of at least 8.

13. A method of reducing loss of wellbore fluid in a wellbore to a formation, comprising:
introducing into the wellbore a fluid composition comprising one or more synthetic fibers and one or more particulate solids, wherein the fluid composition contains the one or more synthetic fibers at 0.25 wt % to 3 wt % of the weight of the one or more particulate solid,
wherein the wellbore fluid composition contains substantially no synthetic fiber having a length equal to or more than 8 mm;
wherein the one or more synthetic fibers have a denier of at least 2.

14. The method of claim 13 , wherein the method further comprises applying pressure to drive the fluid composition into the formation.

15. The method of claim 13 , further comprising circulating an acid wash subsequent to the introduction of the fluid composition.

16. The method of claim 13 , further comprising:
introducing at least one spacer pill is introduced into the wellbore before introducing the fluid composition.

17. The method of claim 13 , further comprising:
introducing at least one spacer pill after the fluid composition is introduced into the wellbore.

18. A method of reducing loss of wellbore fluid in a wellbore to a formation, comprising:
introducing into the wellbore a fluid composition comprising one or more synthetic fibers; and
introducing a second fluid composition comprising one or more particulate solids,
wherein the one or more synthetic fibers in the fluid composition are present at 0.25 wt % to 3 wt % of the weight of the added particulate solid in the second fluid composition;
wherein the wellbore fluid composition contains substantially no synthetic fiber having a length equal to or more than 8 mm;
wherein the one or more synthetic fibers have a denier of at least 2.

19. The method of claim 18 , wherein the method further comprises applying pressure to drive the fluid composition into the formation.

20. The method of claim 18 , further comprising circulating an acid wash subsequent to the introduction of the fluid composition.

21. The method of claim 18 , wherein the one or more synthetic fibers have a length within the range of 4 mm to 7 mm.

22. The method of claim 18 , wherein the at least one synthetic fiber selected from a group consisting of nylon, polyesters, polyethylene terephthalate, polytriphenylene terephthalate, polybutylene terephthalate has a diameter within the range of 5 microns to 15 microns.

Assignees

• Mi Llc

Inventors

• Arias Prada Jorge
• Young Steven Philip
• Guo Quanxin
• Moffitt John D

Classifications

• C09K8/424 Primary

  using "spacer" compositions · CPC title

• E21B43/16

  Enhanced recovery methods for obtaining hydrocarbons · CPC title

• C09K2208/08

  Fiber-containing well treatment fluids · CPC title

• C09K8/426

  for plugging · CPC title

• E21B33/138

  Plastering the borehole wall; Injecting into the formation · CPC title