Systems and methods for sample characterization

Patent metadata

Field	Value
Publication number	US-10024755-B2
Application number	US-201514861925-A
Country	US
Kind code	B2
Filing date	Sep 22, 2015
Priority date	Sep 30, 2014
Publication date	Jul 17, 2018
Grant date	Jul 17, 2018

Abstract

The present disclosure relates to systems and methods for determining an integrity of a sample chamber. In certain embodiments, formation fluid is collected from a subterranean formation within a sample chamber disposed in a downhole tool, the downhole tool is withdrawn from a wellbore, an estimated surface pressure of the collected formation fluid is determined, the estimated surface pressure of the collected formation fluid is compared with an actual surface pressure of the sample chamber, and the integrity of the sample chamber is determined based on the comparison of the estimated surface pressure and the actual surface pressure.

First claim

What is claimed is:

1. A method, comprising:
collecting formation fluid from a subterranean formation within a sample chamber disposed in a downhole tool;
withdrawing the downhole tool from a wellbore;
determining an estimated surface pressure of the collected formation fluid;
comparing the estimated surface pressure of the collected formation fluid with an actual surface pressure of the sample chamber;
determining an integrity of the sample chamber based on the comparison of the estimated surface pressure and the actual surface pressure; and
improving accuracy of analysis by the downhole tool on the subterranean formation based on the determined integrity of the sample chamber;
wherein determining an estimated surface pressure comprises:
determining fluid fractions present in the sample chamber;
determining a change in volume of water, if present in the formation fluid, from subterranean formation conditions to surface conditions; and
determining the estimated surface pressure based on the fluid fractions and change in volume of water, if present.

2. The method of claim 1 , comprising determining a thermal expansion coefficient of the collected formation fluid.

3. The method of claim 1 , comprising:
generating a phase envelope of the formation fluid using an equation of state model;
determining a bubble point of the formation fluid at surface conditions based on the generated phase envelope; and
determining the number of phases present in the sample chamber based on comparing the bubble point with the estimated surface pressure.

4. A method, comprising:
collecting formation fluid from a subterranean formation within a sample chamber disposed in a downhole tool;
withdrawing the downhole tool from a wellbore:
determining an estimated surface pressure of the collected formation fluid;
comparing the estimated surface pressure of the collected formation fluid with an actual surface pressure of the sample chamber;
determining an integrity of the sample chamber based on the comparison of the estimated surface pressure and the actual surface pressure; and
improving accuracy of analysis by the downhole tool on the subterranean formation based on the determined integrity of the sample chamber;

wherein determining an estimated surface pressure comprises:
determining mole fractions of components of the formation fluid using an equation of state model;
determining a formation molar volume of the formation fluid at subterranean formation conditions based on the mole fractions and the equation of state model;
assuming an initial value of the estimated surface pressure;
determining a first surface molar volume of the formation fluid at surface conditions based on a ratio of a formation fluid volume at surface conditions to a formation fluid volume at downhole conditions;
determining a second surface molar volume of the formation fluid at surface conditions based on the equation of state model; and
comparing the first and second surface molar volumes and updating the initial value of the estimated surface pressure based on the comparison to obtain the estimated surface pressure.

5. A method, comprising:
collecting formation fluid from a subterranean formation within a sample chamber disposed in a downhole tool;
withdrawing the downhole tool from a wellbore;
determining an estimated surface pressure of the collected formation fluid;
comparing the estimated surface pressure of the collected formation fluid with an actual surface pressure of the sample chamber;
improving accuracy of analysis by the downhole tool on the subterranean formation based on the determined integrity of the sample chamber; and
using the determined integrity of the sample chamber to improve accuracy of analysis by the downhole tool on the subterranean formation;

wherein determining an estimated surface pressure comprises:
determining mole fractions of components of the formation fluid using an equation of state model;
determining a formation molar volume of the formation fluid at subterranean formation conditions based on the mole fractions and the equation of state model;
assuming an initial value of the estimated surface pressure;
determining a surface molar volume of the formation fluid at surface conditions based on the equation of state model; and
comparing the formation molar volume and the surface molar volume and updating the initial value of the estimated surface pressure based on the comparison to obtain the estimated surface pressure.

6. A method, comprising:
determining an estimated surface pressure of a collected formation fluid stored in a sample chamber;
comparing the estimated surface pressure of the collected formation fluid with an actual surface pressure of the sample chamber;
determining an integrity of the sample chamber based on the comparison of the estimated surface pressure and the actual surface pressure; and
using the determined integrity of the sample chamber to improve accuracy of analysis by the downhole tool on the subterranean formation;
wherein determining an estimated surface pressure comprises:
determining fluid fractions present in the sample chamber;
determining a change in volume of water, if present in the formation fluid, from subterranean formation conditions to surface conditions; and
improving accuracy of analysis by the downhole tool on the subterranean formation based on the determined integrity of the sample chamber.

7. The method of claim 6 , comprising determining a thermal expansion coefficient of the collected formation fluid.

8. The method of claim 6 , comprising collecting formation fluid from a subterranean formation within the sample chamber disposed in a downhole tool.

9. The method of claim 6 , comprising:
generating a phase envelope of the formation fluid using an equation of state model;
determining a bubble point of the formation fluid at surface conditions based on the generated phase envelope; and
determining the number of phases present in the sample chamber based on comparing the bubble point with the estimated surface pressure.

10. A method, comprising:
determining an estimated surface pressure of a collected formation fluid stored in a sample chamber;
comparing the estimated surface pressure of the collected formation fluid with an actual surface pressure of the sample chamber;
determining an integrity of the sample chamber based on the comparison of the estimated surface pressure and the actual surface pressure; and
improving accuracy of analysis by the downhole tool on the subterranean formation based on the determined integrity of the sample chamber;

wherein determining an estimated surface pressure comprises:
determining mole fractions of components of the formation fluid using an equation of state model;
determining a formation molar volume of the formation fluid at subterranean formation conditions based on the mole fractions and the equation of state model;
assuming an initial value of the estimated surface pressure;
determining a first surface molar volume of the formation fluid at surface conditions based on a ratio of a formation fluid volume at surface conditions to a formation fluid volume at downhole conditions;
determining a second surface molar volume of the formation fluid at surface conditions based on the equation of state model; and
comparing the first and second surface molar volumes and updating the initial value of the estimated surface pressure based on the comparison to obtain the estimated surface pressure.

11. A method, comprising:
determining an estimated surface pressure of a collected formation fluid stored in a sample chamber;
comparin

Assignees

• Schlumberger Technology Corp

Inventors

• Zuo Youxiang
• Mishra Vinay K
• Dumont Hadrien
• Gisolf Adriaan
• Babin Christopher
• Ayan Cosan
• Barbosa Beatriz E

Classifications

• G01M3/3272 Primary

  for verifying the internal pressure of closed containers · CPC title

• E21B49/10

  using side-wall fluid samplers or testers · CPC title

• E21B49/082

  Wire-line fluid samplers (E21B49/083 takes precedence) · CPC title