Gel prediction modeling of wellbore fluids using rheology measurements

Patent metadata

Field	Value
Publication number	US-11300490-B2
Application number	US-201816610212-A
Country	US
Kind code	B2
Filing date	Dec 20, 2018
Priority date	Dec 20, 2018
Publication date	Apr 12, 2022
Grant date	Apr 12, 2022

Abstract

Systems and methods for adjusting well operations utilize measured values and curve fitting to determine predicted values of the gel strength of well-treatment fluids. The systems and methods are exemplified by first measuring a plurality of measured values representative of the gel strength of the well-treatment fluid, then determining a mathematical function that fits the plurality of measured values. From the mathematical function, the projected values are determined. The projected values are representative of the gel strength for the well-treatment fluid after a projected-value static period.

First claim

What is claimed is:

1. A method of adjusting a well operation, wherein the well operation uses a well-treatment fluid having a gel strength, the method comprising:
measuring a plurality of measured values representative of the gel strength of the well-treatment fluid, wherein each of the measured values represent gel strength for a different static period than the other measured values such that there is a first measured value that is a GS-0 sec measured value, and there is a second measured value for a second static period and third measured value for a third static period, and wherein the GS-0 sec measured value is measured either (a) within a 2 sec static period after shearing or (b) measured at a shear rate from above 0 s −1 to 170 s −1 , such that the well treatment fluid has no gel structure;
determining a mathematical function that fits the plurality of measured values;
determining from the mathematical function a projected value representative of the gel strength for the well-treatment fluid after a projected-value static period, wherein the projected-value static period is different from the static period of each of the measured values; and
adjusting at least one of (a) an operational parameter of the use of the well-treatment fluid in the well operation or (b) the composition of the well-treatment fluid based on the projected value.

2. The method of claim 1 , wherein the GS-0 sec measured value is measured within a 2 sec static period after shearing, and the second static period and the third static period are from 1 minute to 20 minutes, and the second static period is not the same as the third static period.

3. The method of claim 1 , wherein the GS-0 sec measured value is measured at a shear rate from above 0 s −1 to 170 s −1 , and the second static period and the third static period are from 1 minute to 20 minutes, and the second static period is not the same as the third static period.

4. The method of claim 3 , wherein the second static period is from 3 minutes to 7 minutes, and the third static period is from 8 minutes to 12 minutes.

5. The method of claim 3 , wherein the projected value is determined with the projected-value static period being selected from a range of 5 to 15 seconds or from 20 minutes to 1 hour.

6. The method of claim 5 , wherein the well-treatment fluid is a drilling fluid which is used in a drilling operation in the well, and wherein the step of adjusting involves determining the operational parameters to use when restarting fluid flow after flow of drilling fluid into the well has been stopped, and the projected-value static period is the period of time during which the flow of drilling fluid has been stopped.

7. The method of claim 6 , wherein a viscometer is used in measuring the plurality of measured values.

8. The method of claim 7 , wherein the plurality of measured values and the projected values are selected from gel strength, viscosity and shear stress.

9. The method of claim 1 , wherein the projected value comprises two or more projected values with each projected value being determined after a different projected-value static period.

10. The method of claim 9 , wherein there is a first projected value determined for a first projected-value static period selected from a range of 5 to 15 seconds, and there is a second projected value determined for a second projected-value static period selected from a range of 20 minutes to 1 hour.

11. The method of claim 1 , wherein a viscometer is used in measuring the plurality of measured values.

12. The method of claim 1 , wherein the plurality of measured values and the projected values are selected from gel strength, viscosity and shear stress.

13. A method of restarting flow of a drilling fluid in a drilling operation after a period of static drilling fluid flow, wherein the drilling fluid has a gel strength, the method comprising:
measuring a plurality of measured values representative of the gel strength of the drilling fluid, wherein each of the measured values represents gel strength for a different static period than the other measured values such that there is a first measured value that is a GS-0 sec measured value, and there is a second measured value for a second static period and third measured value for a third static period, and wherein the GS-0 sec measured value is measured either (a) within a 2 sec static period after shearing or (b) measured at a shear rate from above 0 s −1 to 170 s −1 , such that the well treatment fluid has no gel structure;
determining a mathematical function that fits the plurality of measured values;
determining from the mathematical function a projected value representative of the gel strength for the drilling fluid at a projected-value static period wherein the projected-value time is equivalent to the period of static drilling fluid flow; and
applying at least one operational parameter for the restarting of the flow of drilling fluid based on the projected value.

14. The method of claim 13 , wherein the GS-0 sec measured value is measured either (a) within a 2 sec static period after shearing, and the second static period and the third static period are from 1 minute to 20 minutes, and the second static period is not the same as the third static period.

15. The method of claim 14 , wherein the second static period is from 3 minutes to 7 minutes, and the third static period is from 8 minutes to 12 minutes.

16. The method of claim 14 , wherein the projected value is determined with the projected-value static period being selected from a range of 5 to 15 seconds or from 20 minutes to 1 hour.

17. The method of claim 13 , wherein GS-0 sec measured value is measured at a shear rate from above 0 s −1 to 170 s −1 , and the second static period and the third static period are from 1 minute to 20 minutes, and the second static period is not the same as the third static period.

18. The method of claim 13 , wherein a viscometer is used in measuring the plurality of measured values.

19. The method of claim 13 , wherein the plurality of measured values and the projected values are selected from gel strength, viscosity and shear stress.

20. The method of claim 13 , further comprising determining a second projected value representative of the gel strength after a second projected value static period, and adjusting the composition of the well-treatment fluid based on the second projected value.

Assignees

• Halliburton Energy Services Inc

Inventors

• Kulkarni Sandeep D
• Mahajan Lalit N
• Dotson Adam Robert
• Jamison Dale E

Classifications

• E21B41/00

  Equipment or details not covered by groups E21B15/00 - E21B40/00 · CPC title

• E21B21/06 Primary

  Arrangements for treating drilling fluids outside the borehole · CPC title

• E21B49/00

  Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells · CPC title

• E21B21/08 Primary

  Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure (valve arrangements therefor E21B21/10) · CPC title

• E21B21/062 Primary

  by mixing components · CPC title