Determining hydrocarbon gas maturity

Patent metadata

Field	Value
Publication number	US-10823716-B2
Application number	US-201815868782-A
Country	US
Kind code	B2
Filing date	Jan 11, 2018
Priority date	Jan 11, 2018
Publication date	Nov 3, 2020
Grant date	Nov 3, 2020

Abstract

A measured wetness of and a δ 13 C associated with a gas sample from a hydrocarbon formation is received wherein the wetness is a percentage of C2+ by mass. Calculated wetnesses of and δ 13 C values associated with a plurality of gas samples taken from one or more analogous hydrocarbon reservoirs is received. Each wetness is calculated as a percentage of mass within the gas sample. The measured wetness received for the gas sample from among the calculated wetnesses is identified. A δ 13 C is determined from among the δ 13 C values that corresponds to the measured wetness of the gas sample. A gas maturity for the gas sample is determined using the determined δ 13 C.

First claim

What is claimed is:

1. A method comprising:
receiving a measured wetness of and a measured δ 13 C value associated with a test gas sample from a hydrocarbon formation, wherein the measured wetness is a percentage of C 2+ by mass;
receiving a plurality of calculated wetnesses of and a plurality of calculated δ 13 C values associated with a plurality of gas samples taken from one or more analogous hydrocarbon reservoirs that are analogous to the hydrocarbon formation, each of the plurality of calculated wetnesses being a percentage of C 2+ by mass;
identifying, from among the plurality of calculated wetnesses, the measured wetness received for the test gas sample;
determining a corresponding δ 13 C value from among the plurality of calculated δ 13 C values that corresponds to the measured wetness of the test gas sample;
determining a predicted sample VR o (vitrinite reflectance) for the test gas sample based on the corresponding δ 13 C value and a correlation of δ 13 C values to VR o values, the VR o values correlating with gas maturity; and
producing hydrocarbons from the hydrocarbon formation based on gas maturity.

2. The method of claim 1 , further comprising determining the measured wetness of the test gas sample by a gas chromatograph.

3. The method of claim 1 , wherein determining the corresponding δ 13 C value from among the plurality of calculated δ 13 C values comprises:
determining an equation to best fit the plurality of calculated δ 13 C values and the plurality of calculated wetnesses, the equation being used to create a reference line;
plotting the reference line on a plot with a Y-axis representative of a range of the plurality of calculated δ 13 C values and an X-axis representative of a range of the plurality of calculated wetnesses, the measured wetness being identified on the plot; and
identifying a δ 13 C value corresponding to the measured wetness from the reference line.

4. The method of claim 3 , wherein the equation is:
δ 13 C ( C 1 )=−0.62 W− 33.6

where δ 13 C (C 1 ) corresponds to values of δ 13 C of methane in the plurality of gas samples, and “W” corresponds to the plurality of calculated wetnesses of the plurality of gas samples.

5. The method of claim 3 , wherein the equation is:
δ 13 C ( C 2 )=−0.53 W− 24.8

where δ 13 C (C 2 ) corresponds to values of δ 13 C of ethane in the plurality of gas samples, and “W” corresponds to the plurality of calculated wetnesses of the plurality of gas samples.

6. The method of claim 3 , wherein the equation is:
δ 13 C ( C 3 )=−0.63 W− 20.3

where δ 13 C (C 3 ) corresponds to values of δ 13 C of propane in the plurality of gas samples, and “W” corresponds to the plurality of calculated wetnesses of the plurality of gas samples.

7. The method of claim 1 , further comprising:
determining that the measured wetness is within a specified range of values, the specified range of values indicative of an isotopic reversal.

8. The method of claim 7 , wherein the specified range of values for the measured wetness is between 0% and 15%.

9. The method of claim 1 , wherein the correlation of δ 13 C values to VR o values used for determining the predicted sample VR o for the test gas sample comprises the following equation:
δ 13 C ( C 1 )=15.4 Log 10 VR o −41.3

wherein δ 13 C (C 1 ) is δ 13 C of methane.

10. The method of claim 1 , wherein the test gas sample comprises methane and ethane, methane within the test gas sample has a predicted methane sample VR o and ethane within the test gas sample has a predicted ethane sample VR o , and the method further comprises comparing the predicted methane sample VR o and the predicted ethane sample VR o .

11. The method of claim 10 , wherein a difference between the predicted methane sample VR o and the predicted ethane sample VR o is below a specified threshold, the method further comprising:
ignoring the predicted ethane sample VR o ; and
determining the predicted sample VR o based on the predicted methane sample VR o .

12. A method comprising:
receiving a test gas sample from a wellbore within a test hydrocarbon formation;
determining a measured wetness of the test gas sample;
determining a measured δ 13 C value associated with the test gas sample;
receiving a plurality of calculated δ 13 C values from a plurality of gas samples with a corresponding plurality of calculated wetnesses of the plurality of gas samples, wherein the plurality of gas samples are taken from one or more analogous hydrocarbon formations that are analogous to the test hydrocarbon formation;
identifying, from the plurality of calculated wetnesses, the measured wetness of the test gas sample;
determining a corresponding δ 13 C value from among the plurality of calculated δ 13 C values that corresponds to the measured wetness of the test gas sample;
adjusting the measured δ 13 C value to equal the corresponding δ 13 C value to provide an adjusted δ 13 C value;
determining a predicted sample VR o (vitrinite reflectance) for the test gas sample based on the adjusted δ 13 C value and a correlation of δ 13 C values to VR o values, the VR o values correlating with gas maturity; and
producing hydrocarbons from the test hydrocarbon formation based on gas maturity.

13. The method of claim 12 , wherein determining the corresponding δ 13 C value from among the plurality of calculated δ 13 C values comprises determining a best-fit equation from the plurality of calculated δ 13 C values and the plurality of calculated wetnesses, the best-fit equation being used to create a reference line.

14. The method of claim 13 , wherein the best-fit equation is:
δ 13 C ( C 1 )=−0.62 W− 33.6

where δ 13 C (C 1 ) corresponds to values of δ 13 C of methane in the plurality of gas samples, and “W” corresponds to the plurality of calculated wetnesses of the plurality of gas samples.

15. The method of claim 13 , wherein the best-fit equation is:
δ 13 C ( C 2 )=−0.53 W− 24.8

where δ 13 C (C 2 ) corresponds to values of δ 13 C of ethane in the plurality of gas samples, and “W” corresponds to the plurality of calculated wetnesses of the plurality of gas samples.

16. The method of claim 12 , wherein the correlation of δ 13 C values to VR o values used for determining the predicted sample VR o for the test gas sample comprises the following equation:
δ 13 C ( C 2 )=22.6 Log 10 VR o −32.2

wherein δ 13 C (C 2 ) is δ 13 C of ethane.

17. A method comprising:
receiving a dataset comprising calculated wetnesses of and calculated δ 13 C values associated with hydrocarbon gasses;
determining a reference line from the dataset;
plotting the reference line on a plot;
plotting a sample wetness of and a sample δ 13 C value associated with a received gas sample received from a hydrocarbon formation on the plot with the reference line to produce a plotted point;
increasing a δ 13 C value of the plotted point to provide an adjusted plotted point so that a δ 13 C value of the adjusted plotted point matches the reference line;
determining an adjusted δ 13 C value from the adjusted plotted point, wherein the adjusted δ 13 C value is the δ 13 C value of the adjusted plotted point;
determining a predicted sample VR o (vitrinite reflectance) for the received gas sample based on the adjusted δ 13 C value and a correlation of δ 13 C values to VR o values, the VR o values correlating with gas maturity; and
producing hydrocarbons from the hydrocarbon formation based on gas maturity.

18. The method of claim 17 , furthe

Assignees

• Saudi Arabian Oil Co

Inventors

• Lu Feng Hu

Classifications

• G01N33/0047 Primary

  Organic compounds · CPC title

• G01N33/225

  Gaseous fuels, e.g. natural gas · CPC title

• G01V9/007

  by detecting gases or particles representative of underground layers at or near the surface (analysing earth materials G01N33/24; analysing gases per se G01N) · CPC title

• G01V9/00

  Prospecting or detecting by methods not provided for in groups G01V1/00 - G01V8/00 · CPC title

• G01N2030/025

  Gas chromatography · CPC title