Determining source rock maturity based on hydrogen isotopes
A computer receives a measured wetness of and a measured δ 2 H value associated with a test gas sample from a hydrocarbon formation. The measured wetness is a molar ratio of heavy gas compounds over a total gas within the measured sample. The computer receives calculated wetnesses calculated δ 2 H values associated with a gas samples taken from one or more analogous hydrocarbon reservoirs. The measured wetness received for the test gas sample is identified from among the plurality of calculated wetnesses. The computer determines a corresponding δ 2 H value from among the calculated δ 2 H values that corresponds to the measured wetness of the test gas sample. The computer determines a predicted sample VR o (vitrinite reflectance equivalent) for the test gas sample based on the corresponding δ 2 H value and a correlation of δ 2 H values to VR o values. Hydrocarbons are produced from the hydrocarbon formation based on the predicted sample VR o .
1. A method comprising:
receiving, by a computer, a measured wetness of and a measured δ 2 H value associated with a test gas sample from a hydrocarbon formation, wherein the measured wetness which is a molar ratio of heavy gas compounds over a total gas within the measured sample;
receiving, by the computer, a plurality of calculated wetnesses of and a plurality of calculated δ 2 H values associated with a plurality of gas samples taken from one or more analogous hydrocarbon reservoirs that are analogous to the hydrocarbon formation, wherein the calculated wetness is a molar ratio of heavy gas compounds over a total gas within each of the plurality of gas samples;
identifying, from among the plurality of calculated wetnesses, the measured wetness received for the test gas sample;
determining, by the computer, a corresponding δ 2 H value from among the plurality of calculated δ 2 H values that corresponds to the measured wetness of the test gas sample;
determining, by the computer, a predicted sample VR o (vitrinite reflectance equivalent) for the test gas sample based on the corresponding δ 2 H value and a correlation of δ 2 H values to VR o values, the VR o values correlating with gas maturity; and
producing hydrocarbons from the hydrocarbon formation, by a hydrocarbon production system, based on the predicted sample VR o .
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 2 H value from among the plurality of calculated δ 2 H values comprises:
determining an equation to best fit the plurality of calculated δ 2 H values and the plurality of calculated wetnesses, the equation being used to create a reference line;
generating a plot with the reference line, by the computer, the plot having a Y-axis representative of a range of the plurality of calculated δ 2 H 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 2 H value corresponding to the measured wetness from the reference line.
4. The method of claim 3 , wherein the equation is:
δ 2 H( C 1 )=−0.35 W− 114.5
where δ 2 H(C 1 ) corresponds to values of δ 2 H 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 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.
6. The method of claim 5 , wherein the specified range of values for the measured wetness ranges 0% through 7%.
7. The method of claim 1 , further comprising:
determining that the measured wetness is above a specified threshold value, the specified threshold being a threshold indicative of a lack of isotopic reversal.
8. The method of claim 7 , wherein the specified value for the measured wetness is above 7%.
9. 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 2 H value associated with the test gas sample;
receiving a plurality of calculated δ 2 H 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 2 H value from among the plurality of calculated δ 2 H values that corresponds to the measured wetness of the test gas sample;
adjusting the measured δ 2 H value to equal the corresponding δ 2 H value to provide an adjusted δ 2 H value;
determining a predicted sample VR o (vitrinite reflectance equivalent) for the test gas sample based on the adjusted δ 2 H value and a correlation of δ 2 H values to VR o values, the VR o values correlating with gas maturity; and
producing hydrocarbons from the hydrocarbon formation based on the predicted sample VR o .
10. The method of claim 9 , further comprising determining the measured wetness of the test gas sample by a gas chromatograph.
11. The method of claim 9 , wherein determining the corresponding δ 2 H value from among the plurality of calculated δ 2 H values comprises determining a best-fit equation from the plurality of calculated δ 2 H values and the plurality of calculated wetnesses, the best-fit equation being used to create a reference line.
12. The method of claim 11 , wherein the best-fit equation is:
δ 2 H( C 1 )=−0.35 W− 114.5
where δ 2 H(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.
13. The method of claim 9 , further comprising:
determining that the measured wetness is below a threshold value, being at or below the threshold value being indicative of an isotopic reversal.
14. The method of claim 13 , wherein the threshold value for the measured wetness is 7%.