Predicted bias correction for a gas extractor and fluid sampling system

Patent metadata

Field	Value
Publication number	US-2023374902-A1
Application number	US-202217746302-A
Country	US
Kind code	A1
Filing date	May 17, 2022
Priority date	May 17, 2022
Publication date	Nov 23, 2023
Grant date	—

Abstract

A system can flush a drilling fluid sample with a hydrocarbon blend, which includes a determined concentration of at least one chemical species to generate a flushed drilling fluid sample. The system can extract a dissolved gas from the flushed drilling fluid sample. The system can determine a concentration over time of at least one chemical species of the dissolved gas. The system can generate an area per concentration curve based on the concentration over time of the at least one chemical species. The system can determine at least one concentration value of the at least one chemical species. The system can modify the at least one concentration value based on the area per concentration curve. The system can then correct bias caused by the gas extractor and fluid sampling system.

First claim

What is claimed is:

1 . A method, comprising:
controlling a gas extraction and sampling system to flush a drilling fluid sample with a hydrocarbon blend with a determined concentration of at least one chemical species to generate a flushed drilling fluid sample; controlling the gas extraction and sampling system to extract a dissolved gas from the flushed drilling fluid sample; determining a concentration over time of at least one chemical species of the dissolved gas; generating an area per concentration curve based on the concentration over time of the at least one chemical species; determining at least one concentration value of the at least one chemical species of the dissolved gas from the flushed drilling fluid sample; modifying the at least one concentration value based on the area per concentration curve; and correcting bias caused by the gas extraction and sampling system during subsequent gas extraction and sampling system operations using the at least one modified concentration value.

2 . The method of claim 1 , further comprising:
stirring the drilling fluid sample while flushing the drilling fluid sample with the hydrocarbon blend.

3 . The method of claim 1 , wherein flushing the drilling fluid sample with the hydrocarbon blend comprises bubbling gas through the drilling fluid sample.

4 . The method of claim 1 , further comprising:
flushing a headspace of a vessel containing the flushed drilling fluid sample with air, nitrogen, or other non-reactive gas while maintaining the flushed drilling fluid sample at room temperature.

5 . The method of claim 1 , further comprising:
stirring the flushed drilling fluid sample while maintaining the flushed drilling fluid sample at room temperature.

6 . The method of claim 1 , further comprising:
prior to generating an area per concentration curve, heating a vessel holding the flushed drilling fluid sample to a predetermined extraction temperature.

7 . The method of claim 1 , wherein determining a concentration over time of at least one chemical species further comprises flowing a carrier gas through a headspace of a vessel holding the flushed drilling fluid sample to aid in movement of extracted gases to a gas outlet.

8 . The method of claim 1 , wherein modifying the at least one concentration value comprises:
fitting the area per concentration curve with a response curve; and applying the response curve to a determined concentration.

9 . The method of claim 8 , wherein correcting the bias comprises generating a corrected concentration of each species based on applying the response curve to the determined concentration.

10 . A system, comprising:
a gas extraction and sampling system positionable to:
flush a drilling fluid sample with a hydrocarbon blend with a determined concentration of at least one chemical species to generate a flushed drilling fluid sample;
maintain the flushed drilling fluid sample at room temperature for a predetermined amount of time; and
extract a dissolved gas from the flushed drilling fluid sample;
a gas chromatograph connectable to the gas extraction and sampling system to determine a concentration over time of at least one chemical species of the dissolved gas; a processor; and a memory that includes instructions executable by the processor for causing the processor to:
generate an area per concentration curve based on the concentration over time of the at least one chemical species of the dissolved gas;
determine at least one concentration value of the at least one chemical species of the dissolved gas;
modify the at least one concentration value based on the area per concentration curve; and
correct bias caused by the gas extraction and sampling system during subsequent gas extraction and sampling system operations using the at least one modified concentration value.

11 . The system of claim 10 , wherein the gas extraction and sampling system comprises a 20 liter extraction vessel and a constant volume/constant temperature gas extractor (CVCT), wherein the 20 liter extraction vessel connectable to the CVCT.

12 . The system of claim 10 , wherein the gas extraction and sampling system is further positionable to stir the drilling fluid sample while flushing the drilling fluid sample with the hydrocarbon blend.

13 . The system of claim 10 , wherein the gas extraction and sampling system is further positionable to flush the drilling fluid sample with a hydrocarbon blend by bubbling gas through the drilling fluid sample.

14 . The system of claim 10 , wherein the memory further comprises instructions executable by the processor for causing the processor to modify the at least one concentration value by:
fitting the area per concentration curve with a response curve; and applying the response curve to the determined concentration.

15 . The system of claim 10 , wherein the memory further comprises instructions executable by the processor for causing the processor to:
determine a fluid formation characteristic of a subterranean formation using at least one modified concentration value; and modify a hydrocarbon recovery operation based on a determined fluid formation characteristic.

16 . A non-transitory computer-readable medium comprising instructions that are executable by a processor for causing the processor to perform operations comprising:
determining a concentration over time of at least one chemical species of a dissolved gas extracted from a flushed drilling fluid sample; generating an area per concentration curve based on the concentration over time of the at least one chemical species; determining at least one concentration value of the at least one chemical species of the dissolved gas in the flushed drilling fluid sample; modifying the at least one concentration value based on the area per concentration curve; and correcting bias caused by a gas extraction and sampling system during subsequent gas extraction and sampling system operations using the at least one modified concentration value.

17 . The non-transitory computer-readable medium of claim 16 , wherein modifying the at least one concentration value comprises:
fitting the area per concentration curve with a response curve; and applying the response curve to a determined concentration.

18 . The non-transitory computer-readable medium of claim 17 , wherein modifying the at least one concentration value further comprises generating a corrected concentration of the at least one chemical species based on applying the response curve to a determined concentration.

19 . The non-transitory computer-readable medium of claim 17 , wherein fitting the area per concentration curve with a response curve comprises generating the response curve based on the area per concentration curve.

20 . The non-transitory computer-readable medium of claim 16 , further comprising instructions that are executable by the processor for causing the processor to:
determine a fluid formation characteristic of a subterranean formation using the at least one modified concentration value; and modify a hydrocarbon recovery operation based on a determined fluid formation characteristic.

Assignees

• Halliburton Energy Services Inc

Inventors

• Rowe Mathew Dennis

Classifications

• G01N2030/8854

  involving hydrocarbons · CPC title

• G01N33/2841 Primary

  Gas in oils, e.g. hydrogen in insulating oils · CPC title

• G01N33/2823

  Raw oil, drilling fluid or polyphasic mixtures · CPC title

• G01N30/04

  Preparation or injection of sample to be analysed · CPC title

• G01N1/40

  Concentrating samples · CPC title