Methods of cleaning invert emulsion drilling fluids

Patent metadata

Field	Value
Publication number	US-11015107-B2
Application number	US-201515559095-A
Country	US
Kind code	B2
Filing date	Apr 14, 2015
Priority date	Apr 14, 2015
Publication date	May 25, 2021
Grant date	May 25, 2021

Abstract

Various embodiments disclosed relate to methods of cleaning invert emulsion drilling fluids. In various embodiments, the present invention provides a method of cleaning a drilling fluid. The method includes cleaning a used invert emulsion drilling fluid that includes drilled cuttings to form a cleaned invert emulsion drilling fluid. The cleaning includes processing the used invert emulsion drilling fluid in a separator to remove at least some of the drilled cuttings therefrom.

First claim

What is claimed is:

1. A method of cleaning a used invert emulsion drilling fluid comprising an external oil phase, drilled cuttings, and an internal aqueous phase comprising an alcohol, comprising:
processing the used invert emulsion drilling fluid in a primary separator to remove at least some of the drilled cuttings therefrom to form a primary-separator-cleaned invert emulsion drilling fluid; and
processing the primary-separator-cleaned invert emulsion drilling fluid in a thermal separator, wherein the thermal separator heats the primary-separator-cleaned invert emulsion drilling fluid to evaporate at least some water, alcohol, and oil therein away from dissolved and insoluble solids therein to form evaporated liquid and condenses at least some of the evaporated liquid to form a cleaned water phase, a cleaned alcohol phase, and a cleaned oil phase.

2. The method of claim 1 , further comprising processing the drilled cuttings removed in the primary separator in a secondary separator to remove at least some of the used invert emulsion drilling fluid therefrom.

3. The method of claim 2 , wherein the secondary separator comprises a fluid recovery unit, a vertical cuttings dryer, or a combination thereof.

4. The method of claim 1 , wherein the thermal separator comprises a heating unit and a condensation unit, or a first stage condenser and a second stage condenser.

5. The method of claim 1 , further comprising placing the cleaned invert emulsion drilling fluid in a subterranean formation.

6. The method of claim 5 , wherein the internal aqueous phase is about 10 vol % to about 50 vol % of the invert emulsion drilling fluid, and wherein the external oil phase is about 50 vol % to about 90 vol % of the invert emulsion drilling fluid.

7. The method of claim 5 , wherein the alcohol is at least about 40 wt % of the aqueous phase, wherein the alcohol is glycerol, and wherein the external oil phase comprises at least one of a synthetic oil, a diesel oil, and a mineral oil.

8. The method of claim 1 , wherein the invert emulsion drilling fluid comprises an emulsifier, and wherein the emulsifier comprises a hydrophobic amine and an organic acid.

9. The method of claim 8 , wherein the organic acid is citric acid.

10. The method of claim 8 , wherein the hydrophobic amine has the structure:
R 1 R 2 N-L 1 -NR 2 R 1 ,
wherein:
at each occurrence R 1 and R 2 are each independently chosen from —H and substituted or unsubstituted (C 1 -C 20 )hydrocarbyl; and
L 1 is a hydrophobic substituted or unsubstituted (C 10 -C 60 )hydrocarbylene.

11. The method of claim 10 , wherein L 1 has the structure:

12. The method of claim 8 , wherein the hydrophobic amine has the structure:

13. The method of claim 1 , wherein the invert emulsion drilling fluid comprises a suspending agent, and wherein the suspending agent is a polymer formed from a diamine or polyamine and a diisocyanate or polyisocyanate.

14. The method of claim 13 , wherein the diamine or polyamine is hydrazine, ethylenediamine, 1,2-propylenediamine, 1,3-propylenediamine, 1-amino-3-methylaminopropane, 1,4-diaminobutane, N,N′-dimethyl-1-ethylenediamine, 1,6-diaminohexane, 1,12-diaminododecane, 2,5-diamino-2,5-dimethylhexane, trimethyl-1,6-hexane-diamine, diethylenetriamine, N,N′,N″-trimethyldiethylenetriamine, triethylenetetraamine, tetraethylenepentamine, pentaethylenehexamine, polyethyleneimine, dipropylenetriamine, tripropylenetetraamine, bis-(3-aminopropyl)amine, bis-(3-aminopropyl)methylamine, piperazine, 1,4-diaminocyclohexane, isophoronediamine, N-cyclohexyl-1,3-propanediamine, bis-(4-amino-cyclohexyl)methane, bis-(4-amino-3-methylcyclohexyl)-methane, bisaminomethyltricyclodecane (TCDdiamine), o-, m- or p-phenylenediamine, 1,2-diamino-3-methylbenzene, 1,3-diamino-4-methylbenzene(2,4-diaminotoluene), 1,3-bisaminomethyl-4,6-dimethylbenzene, 2,4-diamino-3,5-diethyltoluene, 2,6-diamino-3,5-diethyltoluene, 1,4-diaminonaphthalene, 1,6-diaminonaphthalene, 1,8-diaminonaphthalene, 2,7-diaminonaphthalene, bis-(4-amino-phenyl)-methane, polymethylenepolyphenylamine, 2,2-bis-(4-aminophenyl)-propane, 4,4′-oxybisaniline, 1,4-butanediol bis-(3-aminopropyl ether), 2-(2-aminoethylamino)ethanol, 2,6-diamino-hexanoic acid, liquid polybutadienes or acrylonitrile/butadiene copolymers comprising amino groups, polyethers comprising amino groups, or any combination thereof.

15. The method of claim 13 , wherein the diisocyanate or polyisocyanate is at least one of hexamethylenediisocyanate (HDI), toluene-diisocyanate (TDI), 2,2′-diisocyanatodiphenylmethane, 2,4′-diisocyanatodiphenylmethane, 4,4′-diisocyanatodiphenylmethane, polymethylenepolyphenyldiisocyanate (PMDI), naphthalene-diisocyanate (NDI), 1,6-diisocyanato-2,2,4-trimethylhexane, isophorone-diisocyanate, (3-isocyanato-methyl)-3,5,5-trimethyl cyclohexyl isocyanate (IPDI), tris(4-isocyanatophenyl)-methane, phosphoric acid tris-(4-isocyanato-phenyl ester), thiophosphoric acid tris-(4-isocyanato-phenyl ester), or any combination thereof.

16. The method of claim 1 , further comprising:
treating the cleaned water phase with glycerin; and
recycling the cleaned water phase, the cleaned alcohol phase, and the cleaned oil phase to form a cleaned invert emulsion drilling fluid.

17. A method of treating a subterranean formation, comprising:
placing in the subterranean formation an invert emulsion drilling fluid comprising:
about 0.1 vol % to about 80 vol % internal aqueous phase that comprises a (C 3 -C 30 )hydrocarbon polyol;
about 20 vol % to about 90 vol % of an external oil phase;
wherein the invert emulsion drilling fluid is substantially salt-free; and
wherein the invert emulsion drilling fluid comprises an emulsifier, and wherein the emulsifier comprises a hydrophobic amine and an organic acid;

drilling the subterranean formation with the invert emulsion drilling fluid, to form a used invert emulsion drilling fluid comprising drilled cuttings; and
processing the used invert emulsion drilling fluid in a primary separator to remove at least some of the drilled cuttings therefrom to form a primary-separator-cleaned invert emulsion drilling fluid; and
processing the primary-separator-cleaned invert emulsion drilling fluid in a thermal separator, wherein the thermal separator heats the primary-separator-cleaned invert emulsion drilling fluid to evaporate at least some water, alcohol, and oil therein away from dissolved and insoluble solids therein to form evaporated liquid and condenses at least some of the evaporated liquid to form a cleaned water phase, a cleaned alcohol phase, and a cleaned oil phase.

18. A method of cleaning a used salt-free invert emulsion drilling fluid comprising an external oil phase, drilled cuttings, and an internal aqueous phase comprising an alcohol, comprising:
processing the used salt-free invert emulsion drilling fluid in a primary separator to remove at least some of the drilled cuttings therefrom to form a primary-separator-cleaned salt-free invert emulsion drilling fluid; and
processing the primary-separator-cleaned salt-free invert emulsion drilling fluid in a thermal separator, wherein the thermal separator heats the primary-separator-cleaned salt-free invert emulsion drilling fluid to evaporate at least some water, alcohol, and oil therein away from dissolved and insoluble solids therein to form evaporated liquid and condenses at least some o

Assignees

• Halliburton Energy Services Inc

Inventors

• Miller Jeffrey J
• Ayapbergenov Yerzhan
• Newman Katerina V
• Walker Jonathan

Classifications

• C09K2208/26

  Gel breakers other than bacteria or enzymes · CPC title

• C09K2208/08

  Fiber-containing well treatment fluids · CPC title

• E21B21/065 Primary

  Separating solids from drilling fluids · CPC title

• B01D21/262

  by using a centrifuge · CPC title

• C09K8/36 Primary

  Water-in-oil emulsions · CPC title