Filter cake removal compositions and methods of making and using same

Patent metadata

Field	Value
Publication number	US-12024673-B2
Application number	US-202117537077-A
Country	US
Kind code	B2
Filing date	Nov 29, 2021
Priority date	Nov 29, 2021
Publication date	Jul 2, 2024
Grant date	Jul 2, 2024

Abstract

A breaker composition comprising: (i) an acid precursor, (ii) a delaying agent and (iii) an aqueous fluid wherein the breaker composition has an effective operating temperature range of from about 25° C. to about 180° C. A wellbore servicing system comprising (a) an aqueous-based drilling fluid, wherein the aqueous-based drilling fluid forms water-wet solids in the wellbore; and (b) a breaker composition comprising (i) an acid precursor, (ii) a delaying agent and (iii) an aqueous fluid. A method of dissolving a filtercake comprising contacting the filtercake with a breaker solution comprising (i) an acid precursor, (ii) a delaying agent and (iii) an aqueous fluid wherein the filtercake comprises calcium carbonate.

First claim

We claim:

1. A breaker composition comprising: (i) an acid precursor, (ii) a delaying agent comprising an inorganic chelating salt, a phosphate or a combination thereof and (iii) an aqueous fluid wherein the breaker composition has an effective operating temperature range of from about 25° C. to about 180° C.,
wherein the delaying agent is present in an amount of from about 2 wt./vol. % to about 25 wt./vol. %.

2. The breaker composition of claim 1 wherein the delaying agent comprises sodium hexametaphosphate (SHMP).

3. The breaker composition of claim 1 wherein the delaying agent comprises monosodium phosphate, disodium phosphate, sodium triphosphate, or a combination thereof.

4. The breaker composition of claim 1 wherein the delaying agent comprises the combination of the inorganic chelating salt and the phosphate.

5. The breaker composition of claim 1 wherein the acid precursor comprises a reactive ester, the delaying agent comprises sodium hexametaphosphate (SHMP), and the aqueous fluid comprises a brine, comprising KCl or NaBr.

6. The breaker composition of claim 1 wherein the acid precursor comprises lactic acid derivatives; esters that are water soluble or partially water soluble; formates that are water soluble or partially water soluble; esters or polyesters of glycerol; esters of acetic acid and glycerol; aliphatic polyesters; poly(lactides); poly(glycolides); poly(ε-caprolactones); poly(hydroxybutyrates); poly(anhydrides); aliphatic polycarbonates; polyphosphazenes; poly(ortho esters); orthoesters; esters of oxalic acid; poly(amino acids); esters of propionic acid; esters of butyric acid; halide esters; esters of nitric acid, sulphuric acid, sulphonic acid, sulphinic acid, phosphoric acid, phosphorous acid, phosphoric acid, phosphonic acid, phosphinic acid, sulphamic acid; derivatives thereof or a combination thereof.

7. The breaker composition of claim 1 wherein the acid precursor is present in an amount of from about 5 vol./vol. % to about 30 vol./vol. % based on the total volume of the composition.

8. The breaker composition of claim 1 wherein the aqueous fluid comprises a brine.

9. The breaker composition of claim 8 wherein the brine comprises KCl, NaCl, NaBr, CaCl 2 ), CaBr 2 , ZrBr 2 , sodium formate, potassium formate, cesium formate, or a combination thereof.

10. The breaker composition of claim 1 wherein the aqueous fluid is present in an amount of from about 40 vol./vol. % to about 95 vol./vol. % based on the total volume of the composition.

11. A wellbore servicing system comprising:
(a) an aqueous-based drilling fluid, wherein the aqueous-based drilling fluid forms water-wet solids in the wellbore; and
(b) a breaker composition comprising (i) an acid precursor, (ii) a delaying agent comprising an inorganic chelating salt, a phosphate or a combination thereof, and (iii) an aqueous fluid,
wherein the delaying agent is present in an amount of from about 2 wt./vol. % to about 25 wt./vol. %.

12. The wellbore servicing system of claim 11 wherein a wellbore temperature ranges from about 25° C. to about 180ºC.

13. The wellbore servicing system of claim 11 wherein the water-wet solids form a filtercake.

14. The wellbore servicing system of claim 11 wherein the acid precursor comprises a reactive ester, the delaying agent comprises sodium hexametaphosphate (SHMP), and the aqueous fluid comprises a brine, comprising KCl or NaBr.

15. The wellbore servicing system of claim 11 wherein the delaying agent comprises monosodium phosphate, disodium phosphate, sodium triphosphate, or a combination thereof.

16. A method of dissolving a filtercake comprising:
contacting the filtercake with the breaker composition of claim 1 comprising (i) an acid precursor, (ii) a delaying agent and (iii) an aqueous fluid wherein the filtercake comprises calcium carbonate.

17. The method of claim 16 wherein contacting occurs at a temperature ranging from about 25° ° C. to about 180ºC.

18. The method of claim 17 wherein the delaying agent comprises sodium hexametaphosphate (SHMP).

19. The method of claim 16 wherein the acid precursor comprises a reactive ester.

20. The method of claim 16 wherein the aqueous fluid comprises a brine.

21. The breaker composition of claim 1 wherein the delaying agent is present in an amount of from about 2 wt./vol. % to about 20 wt./vol. % based on the total weight and volume of the composition.

Assignees

• Halliburton Energy Services Inc

Inventors

• Kadam Sunita S
• Devarapalli V Ramireddy
• Lad Rajashree

Classifications

• C09K8/06

  Clay-free compositions (containing inorganic compounds only C09K8/05) · CPC title

• E21B37/06

  using chemical means for preventing or limiting {, e.g. eliminating,} the deposition of paraffins or like substances · CPC title

• E21B2200/08

  Down-hole devices using materials which decompose under well-bore conditions · CPC title

• C09K2208/26

  Gel breakers other than bacteria or enzymes · CPC title

• C09K8/504

  Compositions based on water or polar solvents (C09K8/502 takes precedence) · CPC title