Invert emulsion transition fluid containing calcium aluminate cement

Patent metadata

Field	Value
Publication number	US-9663702-B2
Application number	US-201213599978-A
Country	US
Kind code	B2
Filing date	Aug 30, 2012
Priority date	Aug 30, 2012
Publication date	May 30, 2017
Grant date	May 30, 2017

Abstract

A transition fluid comprises: a hydrocarbon liquid, wherein the hydrocarbon liquid is the external phase of the transition fluid; an aqueous liquid, wherein the aqueous liquid is the internal phase of the transition fluid and wherein the aqueous liquid comprises a water-soluble salt; and a calcium aluminate cement. A method of cementing in a subterranean formation comprises: introducing the transition fluid into the subterranean formation; and introducing a cement composition into the subterranean formation, wherein the step of introducing the cement composition is performed after the step of introducing the transition fluid and wherein the cement composition comprises cement and water.

First claim

What is claimed is:

1. A method of cementing in a subterranean formation comprising:
introducing a transition fluid into the subterranean formation, wherein the transition fluid is an invert emulsion and comprises:
a hydrocarbon liquid, wherein the hydrocarbon liquid is the external phase of the transition fluid;
an aqueous liquid, wherein the aqueous liquid is the internal phase of the transition fluid and wherein the aqueous liquid comprises a water-soluble salt, wherein the salt is in a concentration such that the aqueous liquid has a water phase salinity in the range of 150,000 to 300,000 parts per million and the salt has a concentration so that the transition fluid has a density within +/−10% of a drilling fluid used in forming a wellbore in the subterranean formation and the transition fluid has a density in the range of 12 ppg to 20 ppg;
a calcium aluminate cement, wherein the calcium aluminate cement is in a concentration in the range of 25 to 110 pounds per barrel of the transition fluid; and
a surfactant in a concentration in the range of about 5 to about 20 pounds per barrel of the transition fluid, wherein the surfactant is a hydroxyl thioether-based gemini surfactant; and

introducing a cement composition into the subterranean formation, wherein the step of introducing the cement composition is performed after the step of introducing the transition fluid and wherein the cement composition comprises cement and water; and
contacting at least a portion of the cement composition with the transition fluid to provide a contaminated cement composition in the subterranean formation, wherein the contaminated cement composition comprises at least a 20% increase in compressive strength compared to the same cement composition contaminated with a fluid comprising the same hydrocarbon liquid and aqueous liquid of the transition fluid, but which does not comprise the same surfactant and the calcium aluminate cement of the transition fluid, and wherein the contamination is 10% by volume of the cement composition.

2. The method according to claim 1 , wherein the hydrocarbon liquid is selected from the group consisting of: a fractional distillate of crude oil; a fatty derivative of an acid, an ester, an ether, an alcohol, an amine, an amide, or an imide; a saturated hydrocarbon; an unsaturated hydrocarbon; a branched hydrocarbon; a cyclic hydrocarbon; and any combination thereof.

3. The method according to claim 1 , wherein the aqueous liquid is selected from the group consisting of brackish water and saltwater, in any combination thereof in any proportion.

4. The method according to claim 1 , wherein the salt for the aqueous liquid is selected from the group consisting of sodium chloride, calcium chloride, calcium bromide, potassium chloride, potassium bromide, magnesium chloride, and any combination thereof in any proportion.

5. The method according to claim 1 , wherein the calcium aluminate cement is in a sufficient concentration such that the transition fluid is capable of providing a compressive strength of at least 900 psi (6.2 MPa) to a contaminated cement composition comprising cement and water, and having 10% by volume contamination with the transition fluid at a curing temperature of 90° F. (32.2° C.) and a time of at least 24 hours.

6. The method according to claim 5 , wherein the surfactant is a water-wetting agent.

7. The method according to claim 5 , wherein the surfactant is capable of decreasing the plastic viscosity of the transition fluid compared to a transition fluid without the surfactant.

8. The method according to claim 5 , wherein the surfactant is in a concentration such that a test transition fluid consisting essentially of the hydrocarbon liquid, the aqueous liquid, the calcium aluminate cement, and the surfactant, and in the same proportions as the transition fluid has a lower plastic viscosity than a substantially identical test transition fluid without the surfactant when tested at a temperature of 120° F. (48.9° C.).

9. The method according to claim 5 , wherein the surfactant is in a concentration in the range of 10 to 20 pounds per barrel of the transition fluid.

10. The method according to claim 5 , wherein the transition fluid has a plastic viscosity in the range of 10 to 150 centipoise at the bottomhole temperature and pressure of the subterranean formation.

11. The method according to claim 5 , further comprising the step of introducing an oil-based drilling fluid into the subterranean formation, wherein the step of introducing the oil-based drilling fluid is performed prior to the step of introducing the transition fluid.

12. The method according to claim 11 , wherein the transition fluid has a density similar to the oil-based drilling fluid.

13. The method according to claim 11 , wherein the transition fluid has a plastic viscosity similar to the oil-based drilling fluid.

14. The method according to claim 5 , further comprising the step of introducing a spacer fluid into the subterranean formation, wherein the step of introducing the spacer fluid is performed before or after the step of introducing the transition fluid.

15. The method according to claim 5 , further comprising the step of allowing the cement composition to set, wherein the step of allowing is performed after the step of introducing the cement composition into the subterranean formation.

16. The method of claim 5 wherein the surfactant is of sufficient concentration to spontaneously form a reverse-micelle or micelle.

17. A method of cementing in a subterranean formation comprising:
introducing a transition fluid into the subterranean formation, wherein the transition fluid is an invert emulsion and comprises:
a hydrocarbon liquid, wherein the hydrocarbon liquid is the external phase of the transition fluid;
an aqueous liquid, wherein the aqueous liquid is the internal phase of the transition fluid and wherein the aqueous liquid comprises a water-soluble salt, wherein the salt is in a concentration such that the aqueous liquid has a water phase salinity in the range of 150,000 to 300,000 parts per million and the salt has a concentration so that the transition fluid has a density within +/−10% of a drilling fluid used in forming a wellbore in the subterranean formation and the transition fluid has a density in the range of 12 ppg to 20 ppg;
a calcium aluminate cement, wherein the calcium aluminate cement is in a concentration in the range of 25 to 110 pounds per barrel of the transition fluid; and
a surfactant in a concentration in the range of about 5 to about 20 pounds per barrel of the transition fluid, wherein the surfactant is a hydroxyl thioether-based gemini surfactant; and

introducing a cement composition into the subterranean formation, wherein the step of introducing the cement composition is performed after the step of introducing the transition fluid and wherein the cement composition comprises cement and water; and
contacting at least a portion of the cement composition with the transition fluid to provide a contaminated cement composition in the subterranean formation, wherein the contamination is 10% by volume of the cement composition, and wherein the contaminated cement composition has a compressive strength of greater that 1200 psi (6.9 MPa) at a curing temperature of 90° F. (32.2° C.) and a time of at least 24 hours.

18. A method of cementing in a subterranean formation comprising:
introducing a transition fluid into the subterranean formation, wherein the transition fluid is an invert emulsion and comprises:
a hydrocarbon liquid, wherei

Assignees

• Morris Kay A
• Halliburton Energy Services Inc

Inventors

• Morris Kay A

Classifications

• C04B18/08

  Flue dust {, i.e. fly ash} · CPC title

• C04B14/108

  Shale, slate (colliery shale C04B18/125) · CPC title

• C04B22/0026

  Salt water, e.g. seawater · CPC title

• C04B24/02

  Alcohols; Phenols; Ethers · CPC title

• C04B28/06

  Aluminous cements (monolithic refractories or refractory mortars C04B35/66) · CPC title