Colorimetric detection of shale inhibitors and/or salts

Patent metadata

Field	Value
Publication number	US-11029246-B1
Application number	US-202017110717-A
Country	US
Kind code	B1
Filing date	Dec 3, 2020
Priority date	Mar 20, 2020
Publication date	Jun 8, 2021
Grant date	Jun 8, 2021

Abstract

A method of detecting a shale inhibitor and/or a salt content in a wellbore servicing fluid (WSF), the method comprising determining a water salinity of a wellbore servicing fluid; dosing a known volume of the wellbore servicing fluid into a container; optionally adding a known volume of diluent (e.g., water) and mixing to provide a test sample; combining the test sample with a chromophore specific to the shale inhibitor and/or the salt, respectively, and optionally mixing; measuring the shale inhibitor content and/or the salt content, respectively, of the test sample using colorimetry; reporting the data from the measuring to a computer control system; determining a wellbore servicing fluid treatment based on the measured shale inhibitor content and/or salt content; subjecting the wellbore servicing fluid system to the treatment; and optionally waiting for a waiting time to retest the wellbore servicing fluid system and repeating.

First claim

What is claimed is:

1. A method of detecting a salt content of a wellbore servicing fluid (WSF) of a wellbore servicing fluid system as described herein, the method comprising:
(a) determining a water salinity of a wellbore servicing fluid;
(b) dosing an aliquot of the wellbore servicing fluid into a container;
(c) combining the aliquot of the wellbore servicing fluid with a detector compound specific to the salt and mixing to provide a detection solution in the container, wherein the detection solution is characterized by at least one absorption peak wavelength in the range of from about 380 nanometers (nm) to about 760 nm;
(d) measuring the salt content of the detection solution using colorimetry by detecting an absorption intensity for the detection solution at a wavelength within about ±20% of the at least one absorption peak wavelength, comparing the absorption intensity of the detection solution at the wavelength within about ±20% of the at least one absorption peak wavelength with a target absorption intensity to determine the amount of salt in the WSF, and comparing the amount of salt in the WSF with a target amount of the salt;
(e) reporting the data from the measuring at (d) to a computer control system;
(f) determining a wellbore servicing fluid treatment based on the salt content and/or a content of shale inhibitors; and
(g) subjecting the wellbore servicing fluid of the wellbore servicing fluid system to the treatment.

2. The method of claim 1 further comprising:
adding a known volume of diluent and mixing prior to (c); and/or
(h) waiting for a waiting time to retest the wellbore servicing fluid system; and (i) repeating steps (a) through (g) after the waiting time.

3. The method of claim 1 , wherein the wellbore servicing fluid comprises a drilling fluid.

4. The method of claim 3 , wherein the drilling fluid has been recovered from circulation downhole.

5. The method of claim 3 , wherein the wellbore servicing fluid comprises a water based mud (WBM).

6. The method of claim 3 , wherein the wellbore servicing fluid comprises an oil based mud (OBM), and wherein dosing at (b) further comprises separating an aqueous phase from an oil phase, and wherein the aliquot comprises at least a portion of the separated aqueous phase.

7. The method of claim 1 , wherein (d) measuring the salt content using colorimetry at (e) comprises utilizing an analyzer comprising photosensitive dye(s) comprising the chromophore specific to the salt.

8. The method of claim 1 , wherein the salt comprises NaCl, KCl, NaBr, CaCl 2 , CaBr 2 , MgCl 2 , MgBr 2 , ZnBr 2 , an acetate salt, sodium acetate, potassium acetate, ammonium chloride (NH 4 Cl), potassium phosphate, sodium formate, potassium formate, cesium formate, or a combination thereof.

9. The method of claim 8 , wherein the wellbore servicing fluid comprises a brine.

10. The method of claim 1 , wherein the aliquot of the wellbore servicing fluid comprises a solids reduced and/or diluted volume of the wellbore servicing fluid.

11. A method of detecting a shale inhibitor content of a wellbore servicing fluid (WSF) of a wellbore servicing fluid system as described herein, the method comprising:
(a) determining a water phase salinity (WPS) of a wellbore servicing fluid;
(b) dosing an aliquot of the wellbore servicing fluid into a container;
(c) combining the aliquot of the wellbore servicing fluid with a detector compound specific to the shale inhibitor and mixing to provide a detection solution in the container, wherein the detection solution is characterized by at least one absorption peak wavelength in the range of from about 380 nanometers (nm) to about 760 nm;
(d) measuring the shale inhibitor content of the detection solution using colorimetry by detecting an absorption intensity for the detection solution at a wavelength within about ±20% of the at least one absorption peak wavelength, comparing the absorption intensity of the detection solution at the wavelength within about ±20% of the at least one absorption peak wavelength with a target absorption intensity to determine the amount of shale inhibitor in the WSF, and comparing the amount of shale inhibitor in the WSF with a target amount of the shale inhibitor;
(e) reporting the data from the measuring at (d) to a computer control system;
(f) determining a wellbore servicing fluid treatment based on the water phase salinity (WPS) from (a) and the content of shale inhibitor from (d); and
(g) subjecting the wellbore servicing fluid of the wellbore servicing fluid system to the treatment.

12. The method of claim 11 further comprising:
adding a known volume of diluent and mixing prior to (c); and/or
(h) waiting for a waiting time to retest the wellbore servicing fluid system; and (i) repeating steps (a) through (g) after the waiting time.

13. The method of claim 11 , wherein the wellbore servicing fluid comprises a drilling fluid.

14. The method of claim 13 , wherein the drilling fluid has been recovered from circulation downhole.

15. The method of claim 13 , wherein the wellbore servicing fluid comprises a water based mud (WBM).

16. The method of claim 13 , wherein the wellbore servicing fluid comprises an oil based mud (OBM), and wherein dosing at (b) further comprises separating an aqueous phase from an oil phase, and wherein the aliquot comprises at least a portion of the separated aqueous phase.

17. The method of claim 11 , wherein (d) measuring the shale inhibitor content of the detection solution using colorimetry at (d) comprises utilizing an analyzer comprising photosensitive dye(s) comprising the chromophore specific to the shale inhibitor.

18. The method of claim 11 , wherein the shale inhibitor comprises a polymer, a charged polymer, a salt, or a combination thereof.

19. The method of claim 18 , wherein the shale inhibitor comprises a high molecular weight polymer, potassium chloride, sodium chloride, or a combination thereof.

20. The method of claim 11 , wherein the aliquot of the wellbore servicing fluid comprises a solids reduced and/or diluted volume of the wellbore servicing fluid.

Assignees

• Halliburton Energy Services Inc

Inventors

• Jamison Dale E
• Ye Xiangnan

Classifications

• G01N21/78

  producing a change of colour · CPC title

• E21B49/08 Primary

  Obtaining fluid samples or testing fluids, in boreholes or wells · CPC title

• G01N31/22

  using chemical indicators (G01N31/02 takes precedence) · CPC title

• G01N33/2823 Primary

  Raw oil, drilling fluid or polyphasic mixtures · CPC title

• G01N1/38

  Diluting, dispersing or mixing samples · CPC title