Evaluating reservoir oil biodegradation

Patent metadata

Field	Value
Publication number	US-10330665-B2
Application number	US-201514933807-A
Country	US
Kind code	B2
Filing date	Nov 5, 2015
Priority date	Nov 5, 2014
Publication date	Jun 25, 2019
Grant date	Jun 25, 2019

Abstract

Upper and lower asphaltene weight fractions of fluid proximate ends of an oil column are obtained based on measured OD. Upper and lower maltene partial densities are obtained based on the asphaltene weight fractions. A maltene partial density distribution is obtained utilizing the maltene partial densities and a predetermined diffusion model. An asphaltene partial density distribution is obtained based on the maltene partial density distribution and an estimated mass density gradient. An asphaltene weight percentage is obtained based on the asphaltene partial density distribution and the mass density gradient. The asphaltene weight percentage distribution is converted to an OD distribution utilizing a predetermined correlation. An optimization then reduces differences between the OD distribution and the measured OD data to within a predetermined range to refine a biodegradation time of the predetermined diffusion model. A viscosity distribution may be obtained based on the optimized OD distribution.

First claim

What is claimed is:

1. A method, comprising:
conveying a downhole tool within a wellbore, wherein the wellbore extends from a wellsite surface into a subterranean oil column, and wherein the downhole tool is in communication with surface equipment located at the wellsite surface; and
operating at least one of the downhole tool and the surface equipment to:
measure optical density (OD) of fluid at a plurality of depths within the oil column;
obtain upper and lower asphaltene weight fractions of fluid proximate respective ends of the oil column based on the measured OD;
obtain upper and lower maltene partial densities of the fluid proximate the respective oil column ends based on the respective upper and lower asphaltene weight fractions;
obtain a maltene partial density distribution along depth within the oil column utilizing the upper and lower maltene partial densities and a predetermined diffusion model;
obtain an asphaltene partial density distribution along depth within the oil column based on the maltene partial density distribution and a mass density gradient estimated with respect to depth within the oil column;
obtain an asphaltene weight percentage distribution along depth within the oil column based on the asphaltene partial density distribution and the mass density gradient;
convert the asphaltene weight percentage distribution to an OD distribution utilizing a predetermined correlation between asphaltene weight fraction and OD; and
perform an optimization process to reduce differences between the OD distribution and the measured OD to within a predetermined range and refine a biodegradation time of the predetermined diffusion model.

2. The method of claim 1 further comprising operating at least one of the downhole tool and the surface equipment to obtain a viscosity distribution along depth within the oil column based on the optimized OD distribution.

3. The method of claim 1 wherein the upper and lower asphaltene weight fractions are obtained based on the OD measured proximate the respective oil column ends.

4. The method of claim 3 wherein the upper and lower asphaltene weight fractions are obtained utilizing the predetermined correlation between asphaltene weight fraction and OD.

5. The method of claim 1 further comprising operating at least one of the downhole tool and the surface equipment to measure mass density of the fluid at the plurality of depths, wherein the upper and lower maltene partial densities are obtained based on the respective upper and lower asphaltene weight fractions and the mass density measured proximate the respective oil column ends.

6. The method of claim 1 further comprising operating at least one of the downhole tool and the surface equipment to measure temperature of the fluid at the plurality of depths.

7. The method of claim 6 further comprising operating at least one of the downhole tool and the surface equipment to determine that the oil column is a shallow formation having a maximum depth below the wellsite surface of about 1500 meters.

8. The method of claim 7 further comprising operating at least one of the downhole tool and the surface equipment to determine that the oil column has experienced biodegradation based on the measured temperature data, the shallow formation determination, and a comparison of the measured OD to a predicted OD.

9. The method of claim 8 wherein the predicted OD is based on a substantial lack of biodegradation within the oil column.

10. The method of claim 8 further comprising operating at least one of the downhole tool and the surface equipment to generate the predicted OD based on a predetermined relationship between OD and depth within the oil column assuming substantially no biodegradation exists.

11. The method of claim 8 further comprising operating at least one of the downhole tool and the surface equipment to generate the predicted OD based on a predetermined relationship between asphaltene content and depth within the oil column assuming substantially no biodegradation exists.

12. The method of claim 1 further comprising operating at least one of the downhole tool and the surface equipment to estimate the mass density gradient with respect to depth within the oil column by fitting or interpolating the measured mass density data to a polynomial or other function.

13. The method of claim 1 wherein the predetermined correlation between asphaltene weight fraction and OD is a linear relationship determined empirically from data obtained from other wellbores, laboratory data, or other data obtained prior to conveying the downhole tool within the wellbore.

14. The method of claim 1 further comprising operating at least one of the downhole tool and the surface equipment to estimate the biodegradation time utilizing a fitting process and Fick's second law.

15. A system, comprising:
a downhole tool conveyable within a wellbore, wherein the wellbore extends from a wellsite surface into a subterranean oil column; and
surface equipment located at the wellsite surface and in communication with the downhole tool;
wherein the downhole tool and the surface equipment are collectively operable to:
measure optical density (OD) of fluid at a plurality of depths within the oil column;
obtain upper and lower asphaltene weight fractions of fluid proximate respective ends of the oil column based on the measured OD;
obtain upper and lower maltene partial densities of the fluid proximate the respective oil column ends based on the respective upper and lower asphaltene weight fractions;
obtain a maltene partial density distribution along depth within the oil column utilizing the upper and lower maltene partial densities and a predetermined diffusion model;
obtain an asphaltene partial density distribution along depth within the oil column based on the maltene partial density distribution and a mass density gradient estimated with respect to depth within the oil column;
obtain an asphaltene weight percentage distribution along depth within the oil column based on the asphaltene partial density distribution and the mass density gradient;
convert the asphaltene weight percentage distribution to an OD distribution utilizing a predetermined correlation between asphaltene weight fraction and OD; and
perform an optimization process to reduce differences between the OD distribution and the measured OD to within a predetermined range and refine a biodegradation time of the predetermined diffusion model.

16. The system of claim 15 wherein:
the upper and lower asphaltene weight fractions are obtained based on the OD measured proximate the respective oil column ends;
the upper and lower asphaltene weight fractions are obtained utilizing the predetermined correlation between asphaltene weight fraction and OD; and
the predetermined correlation between asphaltene weight fraction and OD is a linear relationship determined empirically from data obtained from other wellbores, laboratory data, or other data obtained prior to conveying the downhole tool within the wellbore.

17. The system of claim 15 wherein the downhole tool and the surface equipment are collectively further operable to:
measure mass density of the fluid at the plurality of depths, wherein the upper and lower maltene partial densities are obtained based on the respective upper and lower asphaltene weight fractions and the mass density measured proximate the respective oil column ends;
measure temperature of the fluid at the plurality of depths;
determine that the oil column is a shallow formation having a maximum depth below the

Assignees

• Schlumberger Technology Corp

Inventors

• Zuo Youxiang
• Mullins Oliver C
• Jackson Richard
• Agarwal Ankit

Classifications

• E21B49/08

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

• G01N33/2888 Primary

  Lubricating oil characteristics, e.g. deterioration (lubricating properties G01N33/30) · CPC title