Thermally-stable, non-precipitating, high-density wellbore fluids

Patent metadata

Field	Value
Publication number	US-11111428-B2
Application number	US-201916571961-A
Country	US
Kind code	B2
Filing date	Sep 16, 2019
Priority date	Oct 17, 2014
Publication date	Sep 7, 2021
Grant date	Sep 7, 2021

Abstract

A wellbore treatment fluid comprising: a base fluid; and a water-soluble salt, the salt comprising: a cation; and an anion, wherein the anion is selected from phosphotungstate, silicotungstate, phosphomolybdate, and silicomolybdate. The treatment fluid can have a density greater than or equal to 13 pounds per gallon. A method of treating a portion of a subterranean formation penetrated by a well comprising: introducing the treatment fluid into the well.

First claim

What is claimed is:

1. A system comprising:
a wellbore that penetrates a subterranean formation; and
a treatment fluid comprising:
(A) a base fluid; and
(B) a water-soluble salt, the salt comprising:
(i) a cation selected from ammonium, phosphonium, quaternary amines, poly-quaternary amines, and rare earth metals; and
(ii) an anion, wherein the anion is selected from phosphotungstate, silicotungstate, and silicomolybdate.

2. The system of claim 1 , wherein the base fluid comprises water, and wherein the water is selected from the group consisting of freshwater, brackish water, saltwater, and any combination thereof.

3. The system of claim 1 , wherein the cation is organic or inorganic.

4. The system of claim 1 , wherein the treatment fluid is thermally stable at temperatures greater than 212 ° F.

5. The system of claim 1 , wherein the treatment fluid is a drilling fluid, a drill-in fluid, a packer fluid, a completion fluid, a spacer fluid, a work-over fluid, or an insulating fluid.

6. The system of claim 1 , further comprising a mixer, wherein the mixer is capable of mixing the treatment fluid.

7. The system of claim 1 , further comprising a pump capable of pumping the treatment fluid into the subterranean formation.

8. The system of claim 1 , wherein the treatment fluid further comprises an additional additive selected from the group consisting of a fluid loss additive, a bridging agent, a friction reducer, a defoaming agent, elastomers, a mechanical property enhancing additive, a lost-circulation material, a filtration-control additive, a gas migration control additive, a thixotropic additive, a viscosifying additive, and combinations thereof.

9. The system of claim 1 , wherein the subterranean formation has a bottomhole temperature greater than 212 ° F.

10. A wellbore treatment fluid comprising:
a base fluid; and
a water-soluble salt, the salt comprising:
a cation selected from ammonium, phosphonium, quaternary amines, poly-quaternary amines, and rare earth metals; and
an anion, wherein the anion is selected from phosphotungstate, silicotungstate, and silicomolybdate.

11. The fluid of claim 10 , wherein the base fluid comprises water, and wherein the water is selected from the group consisting of freshwater, brackish water, saltwater, and any combination thereof.

12. The fluid of claim 10 , wherein the treatment fluid has a density greater than or equal to 13 pounds per gallon.

13. The fluid of claim 10 , wherein the cation is organic or inorganic.

14. The fluid of claim 10 , wherein the type of salt and the concentration of the salt are selected, based on the mass of the salt and the solubility of the salt, to provide a density of at least 13 pounds per gallon to the treatment fluid.

15. The fluid of claim 10 , further comprising an additional salt.

16. The fluid of claim 15 , wherein the additional salt is selected from the group consisting of sodium chloride, calcium chloride, calcium bromide, potassium chloride, potassium bromide, magnesium chloride, and any combinations thereof.

17. The fluid of claim 10 , further comprising an additional additive selected from the group consisting of a fluid loss additive, a bridging agent, a friction reducer, a defoaming agent, elastomers, a mechanical property enhancing additive, a lost-circulation material, a filtration-control additive, a gas migration control additive, a thixotropic additive, a viscosifying additive, and combinations thereof.

18. The fluid of claim 10 , wherein the treatment fluid is thermally stable at temperatures greater than 212 ° F.

19. The system of claim 1 , wherein the treatment fluid is thermally stable at temperatures greater than 350 ° F.

20. The fluid of claim 11 , wherein the treatment fluid is thermally stable at temperatures greater than 350 ° F.

Assignees

• Halliburton Energy Services Inc

Inventors

• Mcdaniel Cato R
• Shumway William W
• Harvey Timothy

Classifications

• C09K8/60

  Compositions for stimulating production by acting on the underground formation · CPC title

• C09K8/02 Primary

  Well-drilling compositions · CPC title

• C09K8/05 Primary

  containing inorganic compounds only, e.g. mixtures of clay and salt · CPC title

• C09K8/40

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

• C09K8/601

  using spacer compositions · CPC title