Fluid loss additives and methods of making and using same

Patent metadata

Field	Value
Publication number	US-9598627-B2
Application number	US-201514697294-A
Country	US
Kind code	B2
Filing date	Apr 27, 2015
Priority date	Sep 29, 2011
Publication date	Mar 21, 2017
Grant date	Mar 21, 2017

Abstract

A non-aqueous wellbore servicing fluid comprising a fluid loss additive wherein the fluid loss additive comprises the reaction product of (i) a functional polymer and (ii) an oligomerized fatty acid. A method of conducting an oil-field operation comprising placing a non-aqueous wellbore servicing fluid downhole wherein the non-aqueous wellbore servicing fluid comprises a fluid loss additive comprising the reaction product of (i) a functional polymer and (ii) an oligomerized fatty acid.

First claim

What is claimed is:

1. A method of conducting an oil-field operation comprising:
placing a non-aqueous wellbore servicing fluid downhole wherein the non-aqueous wellbore servicing fluid comprises a fluid loss additive comprising the reaction product of (i) a functional polymer and (ii) an oligomerized fatty acid,
wherein the functional polymer comprises a maleic anhydride coploymer having a maleic anhydride content of from about 25% to about 75% based on the total weight of the copolymer.

2. The method of claim 1 wherein the oligomerized fatty acid comprises a dimer acid.

3. The method of claim 1 wherein the reaction product is formed by contacting the functional polymer and oligomerized fatty acid to form a reaction mixture and subjecting the reaction mixture to a temperature of from about 100° C. to about 225° C. for a time period of from about 1 hour to about 6 hours.

4. The method of claim 3 wherein the ratio of oligomerized fatty acid to functional polymer in the reaction mixture is in a weight to weight ratio of from about 1:4 to about 4:1.

5. The method of claim 1 wherein the fluid loss additive is present in the non-aqueous wellbore servicing fluid in an amount of from about 0.3 wt. % to about 10 wt. % based on the total weight of the non-aqueous wellbore servicing fluid.

6. The method of claim 1 wherein the non-aqueous wellbore servicing fluid has a high-temperature high-pressure fluid loss at 300° F. that is reduced by greater than about 40% when compared to an otherwise similar non-aqueous wellbore servicing fluid lacking a fluid loss additive comprising the reaction product of (i) a functional polymer and (ii) a oligomerized fatty acid.

7. The method of claim 1 wherein the non-aqueous wellbore servicing fluid further comprises compounds selected from the group consisting of hydrocarbons, olefins, internal olefin based oils, mineral oil, kerosene, diesel oil, fuel oil, synthetic oil, linear or branched paraffins, esters, acetals, mixtures of crude oil, derivatives thereof, or combinations thereof.

8. The method of claim 1 , wherein the oligomerized fatty acid comprises a dimer acid.

9. The method of claim 8 wherein the dimer acid is a self-condensation product of two C 14 -C 18 unsaturated fatty acids.

10. The method of claim 1 wherein the average molecular weight of the functional polymer is from about 10,000 Daltons to about 500,000 Daltons.

11. The method of claim 1 wherein the maleic anhydride copolymer comprises polystyrene-co-maleic anhydride, poly-1-octadecene-co-maleic anhydride, polyethylene-co-maleic anhydride or combinations thereof.

12. The method of claim 1 wherein the non-aqueous wellbore servicing fluid further comprises an oil-based drilling fluid.

13. The method of claim 1 wherein the non-aqueous wellbore servicing fluid further comprises an inverse emulsion.

14. The method of claim 1 wherein the non-aqueous wellbore servicing fluid comprises less than about 30% water by weight of the non-aqueous wellbore servicing fluid.

15. The method of claim 1 wherein the non-aqueous wellbore servicing fluid further comprises an emulsifier.

16. The method of claim 12 further comprising:
circulating the oil-based drilling fluid through a hollow drill stem; and
flowing the oil-based drilling fluid back to a surface in a circulatory repetitive path.

17. The method of claim 16 wherein a filtercake is deposited on the walls of the wellbore.

18. The method of claim 1 wherein the non-aqueous wellbore servicing fluid is prepared on-site.

19. The method of claim 1 wherein the reaction product is obtained from a reaction mixture comprising from about 20 wt. % to about 80 wt. % functional copolymer and from about 80 wt. % to about 20 wt. % oligomerized fatty acid.

Assignees

• Chevron Phillips Chemical Co Lp

Inventors

• Harris Jeffery R
• Evans Frank E

Classifications

• C09K8/64

  Oil-based compositions · CPC title

• E21B33/138

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

• C09K8/502

  Oil-based compositions · CPC title

• C09K8/32 Primary

  Non-aqueous well-drilling compositions, e.g. oil-based · CPC title

• C09K8/36 Primary

  Water-in-oil emulsions · CPC title