Method and system for determining asphaltene onset pressure

Patent metadata

Field	Value
Publication number	US-11946370-B2
Application number	US-202318182799-A
Country	US
Kind code	B2
Filing date	Mar 13, 2023
Priority date	Sep 28, 2017
Publication date	Apr 2, 2024
Grant date	Apr 2, 2024

Abstract

Asphaltene onset pressure of a formation fluid is determined by subjecting the fluid to a plurality of tests where depressurization is conducted at a different depressurization rate for each test while optically monitoring the fluid for asphaltene flocculation. The pressures at which asphaltene flocculation are detected in each test are fit to a curve as a function of depressurization rate, and the curve is extrapolated to a pressure (e.g., 0 psi) to provide the asphaltene onset pressure.

First claim

What is claimed is:

1. A method for determining asphaltene onset pressure of a formation fluid, the method comprising:
a. transmitting an optical signal through a sample of the formation fluid;
b. detecting the optical signal transmitted through the formation fluid sample;
c. decreasing a pressure of the formation fluid sample at a first controlled depressurization rate while monitoring the optical signal transmitted through the formation fluid sample;
d. using results from (c), determining a first pressure at which a change in the optical signal from asphaltene flocculation occurs;
e. repressurizing the formation fluid sample to, or introducing another sample of the formation fluid at a pressure above the first pressure determined at (d);
f. repeating (a) to (d) at least once using at least a second, different depressurization rate to determine a second pressure at which the change in the optical signal from the asphaltene flocculation occurs;
g. fitting at least the determined first and second pressures as a function of the first and second depressurization rates to a curve;
h. determining the asphaltene onset pressure of the formation fluid sample from the curve.

2. The method of claim 1 , further comprising:
positioning a wellbore tool within a wellbore;
drawing the formation fluid into the wellbore tool; and
performing (a) to (f) within the wellbore.

3. The method of claim 2 , wherein, the repressurizing the formation fluid sample or introducing another sample comprises introducing another sample of the formation fluid.

4. The method of claim 1 , wherein the formation fluid sample comprises a volume equal to or less than 1 mL.

5. The method of claim 1 , wherein the transmitted optical signal travels along a path length through the formation fluid sample that is less than 2 mm.

6. The method of claim 1 , further comprising:
determining whether a change in the transmitted optical signal detected at (b) is a result of the asphaltene flocculation in the formation fluid sample, wherein the detecting the optical signal comprises detecting an intensity of the transmitted optical signal at a first and second wavelength.

7. The method of claim 6 , further comprising:
determining a wavelength dependent signal using the intensity of the transmitted optical signal at the first wavelength and the intensity of the transmitted optical signal at the second wavelength.

8. The method of claim 1 , wherein the determining the first pressure at which the change in the optical signal from the asphaltene flocculation occurs comprises:
determining a pressure at which the optical signal changes past a predetermined threshold value.

9. The method of claim 1 , wherein the determining the first pressure at which the change in the optical signal from the asphaltene flocculation occurs comprises:
plotting first and second regions of the optical signal;
fitting curves to the first and second regions of the optical signal;
extrapolating the fitted curves, and
determining a pressure at which the extrapolated fitted curves intercept one another.

10. The method of claim 1 , wherein the fitting comprises:
fitting the determined first and second pressures as the function of the first and second depressurization rates to a power law or other mathematical function.

11. The method of claim 10 , wherein the power law or the other mathematical function includes at least one variable and the at least one variable is set to a constant value.

12. The method of claim 10 , wherein the power law or the other mathematical function includes more than one variable and the more than one variable is set to constant values.

13. The method of claim 1 , wherein the fitting comprises:
fitting a difference between the determined first and second pressures as the function of the first and second depressurization rates and an asphaltene onset pressure of the formation fluid determined from conventional laboratory measurements to a power law or other mathematical function.

14. The method of claim 13 , wherein the power law or the other mathematical function includes at least one variable and the at least one variable is set to a constant value.

15. The method of claim 13 , wherein the power law or the other mathematical function includes more than one variable and the more than one variable is set to constant values.

16. The method of claim 1 , wherein the determining the asphaltene onset pressure comprises:
extrapolating the curve to a depressurization rate not directly measured in the formation fluid sample.

17. The method of claim 16 , wherein the extrapolating comprises:
extrapolating to a depressurization rate of 0 psi/sec.

18. The method of claim 1 , wherein the decreasing the pressure of the formation fluid sample at the first controlled depressurization rate decreases the pressure from a first pressure value and the repressurizing the formation fluid sample to, or introducing another sample of the formation fluid at a pressure above the first pressure determined at (d) comprises repressurizing to the first pressure value.

Assignees

• Schlumberger Technology Corp

Inventors

• Sullivan Matthew T
• Harrison Christopher
• Smythe Elizabeth Jennings

Classifications

• E21B49/0875 Primary

  determining specific fluid parameters · CPC title

• E21B47/06

  Measuring temperature or pressure · CPC title

• E21B47/135

  using light waves, e.g. infrared or ultraviolet waves · CPC title

• E21B49/088

  combined with sampling · CPC title

• E21B49/10

  using side-wall fluid samplers or testers · CPC title