Rheology modifiers

Patent metadata

Field	Value
Publication number	US-9404029-B2
Application number	US-201514621591-A
Country	US
Kind code	B2
Filing date	Feb 13, 2015
Priority date	Apr 30, 2012
Publication date	Aug 2, 2016
Grant date	Aug 2, 2016

Abstract

A non-aqueous wellbore servicing fluid comprising a rheology modifier wherein the rheology modifier comprises a reaction product of a polysulfide, a dimer acid and a polyfunctional amine. A method of conducting an oilfield operation comprising placing an oil-based mud comprising a rheology modifier into a wellbore wherein the rheology modifier comprises a reaction product of a polysulfide, a dimer acid and a polyfunctional amine.

First claim

What is claimed is:

1. A method of servicing a wellbore within a subterranean formation comprising:
placing in the wellbore a composition comprising an oleaginous fluid and a rheology modifier,
wherein the oleaginous fluid is 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, and combinations thereof,
wherein the rheology modifier comprises a reaction product of a polysulfide, a dimer acid and a polyfunctional amine,
wherein the rheology modifier is present in the composition in an amount of from about 0.02 wt. % to about 2.2 wt. % based on the total weight of the composition, and
wherein the composition has a flat rheology.

2. The method of claim 1 wherein the polysulfide comprises di(hydroxyethyl)polysulfides, di(hydroxyethyl)disulfide, di(hydroxyethyl)trisulfide, di(hydroxyethyl)tetrasulfide or homopolymers thereof.

3. The method of claim 1 wherein the polysulfide is characterized by general Formula I:

where each R, R′ and R′″ can be independently selected from the group consisting of hydrogen and an organyl group and x has an average value greater than 2.

4. The method of claim 1 wherein the dimer acid comprises a C12-C24 unsaturated fatty acid.

5. The method of claim 1 wherein the polyfunctional amine comprise a molecule containing at least two amine groups.

6. The method of claim 1 wherein the rheology modifier further comprises a diluent selected from the group consisting of C 16 -C 24 internal olefins, cellulosic ether derivatives, and butyl carbitol.

7. The method of claim 1 wherein the composition has a variation in yield point of less than about 20% over a temperature range of from about 100° F. to about 430° F.

8. The method of claim 1 wherein the composition has a variation in yield point of less than about 10% over a temperature range of from about 100° F. to about 430° F.

9. The method of claim 1 wherein the composition has a variation in yield point of less than about 5% over a temperature range of from about 100° F. to about 430° F.

10. The method of claim 1 wherein the composition has a variation in yield point of less than about 1% over a temperature range of from about 100° F. to about 430° F.

11. The method of claim 1 wherein the composition has a variation in gel strength of less than about 20% over a temperature range of from about 100° F. to about 430° F.

12. The method of claim 1 wherein the composition has a variation in gel strength of less than about 10% over a temperature range of from about 100° F. to about 430° F.

13. The method of claim 1 wherein the composition has a variation in gel strength of less than about 5% over a temperature range of from about 100° F. to about 430° F.

14. The method of claim 1 wherein the composition has a variation in gel strength of less than about 1% over a temperature range of from about 100° F. to about 430° F.

15. The method of claim 1 wherein the composition is pumped through one or more pieces of wellbore servicing equipment during the servicing method and wherein rheology modifier functions as a corrosion inhibitor for the wellbore servicing equipment in the presence of free water.

16. The method of claim 1 wherein the composition is formulated as a drilling fluid.

17. The method of claim 16 wherein the drilling fluid comprises one or more additives selected from the group consisting of weighting agents, glass fibers, carbon fibers, suspending agents, conditioning agents, dispersants, water softeners, oxidation inhibitors, corrosion inhibitors, bacteriacides, thinners, and combinations thereof.

18. The method of claim 16 wherein the drilling fluid is an invert emulsion drilling fluid.

19. The method of claim 16 wherein the method of servicing the wellbore is drilling an offshore well.

20. The method of claim 19 wherein the drilling fluid is subjected to cyclic temperature stresses.

21. The method of claim 1 having a yield point of greater than about 6 lbs/100 ft 2 and a 10 minute gel strength of greater than about 8 lbs/100 ft 2 .

Assignees

• Chevron Phillips Chemical Co Lp

Inventors

• Harris Jeffery R
• Byers Jim D

Classifications

• C09K2208/32

  Anticorrosion additives · CPC title

• Y10S507/904

  Process of making fluids or additives therefor · CPC title

• C09K8/34 Primary

  Organic liquids · CPC title

• Y10S507/939

  Corrosion inhibitor · CPC title

• C09K2208/00

  Aspects relating to compositions of drilling or well treatment fluids · CPC title