Systems and methods for monitoring gas storage in underground reservoirs
Systems and methods presented herein are configured to monitor gas storage in a well and, more specifically, to invert optical measurements to predict the fractional molar composition of an unknown composition of a gas mixture comprised of hydrogen, carbon dioxide, other gases, or combinations thereof, in any underground reservoir or salt dome where hydrogen, carbon dioxide, and/or the other gases are stored or exist.
1. A data processing system, comprising:
one or more processors configured to execute instructions stored on one or more memory media, wherein the instructions, when executed by the one or more processors, cause the data processing system to monitor storage of gas in a well by:
(a) estimating initial mole fractions of one or more components of the gas being stored in the well based on one or more tool parameters of a logging tool disposed within a wellbore of the well in a zone of a subterranean formation;
(b) calculating component densities of the one or more components of the gas based at least in part on the initial mole fractions of the one or more components of the gas;
(c) predicting an optical response and pressure using the one or more tool parameters of the logging tool and the component densities of the one or more components of the gas; and
(d) comparing the predicted optical response and pressure to an optical response and pressure measured by an optical module of the logging tool to determine whether the estimated initial mole fractions and the calculated component densities of the one or more components of the gas are representative of actual mole fractions and component densities of the one or more components of the gas.
2. The data processing system of claim 1 , wherein the gas comprises hydrogen (H 2 ), carbon dioxide (CO 2 ), carbon monoxide (CO), methane (CH 4 ), ethane (C 2 H 6 ), propane (C 3 H 8 ), butane (C 4 H 10 ), pentane (C 5 H 12 ), hexane (C 6 H 14 ), heptane (C 7 H 16 ), octane (C 8 H 18 ), nonane (C 9 H 20 ), decane (C 10 H 22 ), hydrogen sulfide (H 2 S), nitrogen (N 2 ), or some combination thereof.
3. The data processing system of claim 1 , wherein the instructions, when executed by the one or more processors, cause the data processing system to repeat steps (a)-(d) for the zone if the predicted optical response and pressure do not match the measured optical response and pressure within respective predetermined thresholds.
4. The data processing system of claim 1 , wherein the instructions, when executed by the one or more processors, cause the data processing system to move the logging tool to another zone of the subterranean formation, and repeat steps (a)-(d) for the another zone if the predicted optical response and pressure matches the measured optical response and pressure within respective predetermined thresholds.
5. The data processing system of claim 1 , wherein the instructions, when executed by the one or more processors, cause the data processing system to monitor the storage of the gas in the well by:
receiving Raman spectrometer signals obtained by the optical module of the logging tool; and
comparing intensity ratios of the Raman spectrometer signals to reference intensity ratios of one or more reference gases to estimate the initial mole fractions of the one or more components of the gas.
6. The data processing system of claim 1 , wherein the instructions, when executed by the one or more processors, cause the data processing system to perform an intervention in response to determining that the actual mole fractions and/or the actual component densities of the one or more components of the gas are outside of respective predetermined ranges.
7. The data processing system of claim 1 , wherein the one or more tool parameters of the logging tool comprise temperature, pressure, fluid flow rate, measured refraction index, Raman spectrometer signals, or some combination thereof.
8. The data processing system of claim 1 , wherein (b) calculating the component densities of the one or more components of the gas comprises calculating the component densities of the one or more components of the gas based at least in part on the initial mole fractions of the one or more components of the gas.
9. The data processing system of claim 1 , wherein (c) predicting an optical response and pressure comprises predicting the optical response and pressure using the one or more tool parameters of the logging tool and the component densities of the one or more components of the gas in a forward model.
10. A method for monitoring storage of gas in a well, comprising:
(a) estimating, via a data processing system, initial mole fractions of one or more components of the gas being stored in the well based on one or more tool parameters of a logging tool disposed within a wellbore of the well in a zone of a subterranean formation;
(b) calculating, via the data processing system, component densities of the one or more components of the gas based at least in part on the initial mole fractions of the one or more components of the gas;
(c) predicting, via the data processing system, an optical response and pressure using the one or more tool parameters of the logging tool and the component densities of the one or more components of the gas; and
(d) comparing, via the data processing system, the predicted optical response and pressure to an optical response and pressure measured by an optical module of the logging tool to determine whether the estimated initial mole fractions and the calculated component densities of the one or more components of the gas are representative of actual mole fractions and component densities of the one or more components of the gas.
11. The method of claim 10 , wherein the gas comprises hydrogen (H 2 ), carbon dioxide (CO 2 ), carbon monoxide (CO), methane (CH 4 ), ethane (C 2 H 6 ), propane (C 3 H 8 ), butane (C 4 H 10 ), pentane (C 5 H 12 ), hexane (C 6 H 14 ), heptane (C 7 H 16 ), octane (C 8 H 18 ), nonane (C 9 H 20 ), decane (C 10 H 22 ), hydrogen sulfide (H 2 S), nitrogen (N 2 ), or some combination thereof.
12. The method of claim 10 , comprising repeating steps (a)-(d) for the zone if the predicted optical response and pressure do not match the measured optical response and pressure within respective predetermined thresholds.
13. The method of claim 10 , comprising moving the logging tool to another zone of the subterranean formation, and repeating steps (a)-(d) for the another zone if the predicted optical response and pressure matches the measured optical response and pressure within respective predetermined thresholds.
14. The method of claim 10 , comprising:
obtaining, via the optical module of the logging tool, Raman spectrometer signals; and
comparing, via the data processing system, intensity ratios of the Raman spectrometer signals to reference intensity ratios of one or more reference gases to estimate the initial mole fractions of the one or more components of the gas.
15. The method of claim 10 , comprising performing, via the data processing system, performing an intervention in response to determining that the actual mole fractions and/or the actual component densities of the one or more components of the gas are outside of respective predetermined ranges.
16. The method of claim 10 , wherein the one or more tool parameters of the logging tool comprise temperature, pressure, fluid flow rate, measured refraction index, Raman spectrometer signals, or some combination thereof.
17. The method of claim 10 , comprising:
(b) calculating, via the data processing system, the component densities of the one or more components of the gas based at least in part on the initial mole fractions of the one or more components of the gas.
18. The method of claim 10 , comprising:
(c) predicting, via the data processing system, the optical response and pressure using the one or more tool parameters of the logging tool and the component densities of the one or more components of the gas in a forward model.
19. A logging tool, comprising:
an optical module; and
a data processing system configured to monitor storage of gas in a well by:
estimating initial mole fractions of one or more components of the gas being stored in the well based on one or more tool parameters of the logging tool;
calculating component densities of the one or more components of the gas based at least in part on the initial mole fractions of the one or more components of the gas;
predicting an optical response and pressure using the one or more tool parameters of the logging tool and the component densities of the one or more components of the gas; and
comparing the predicted optical response and pressure to an optical response and pressure measured by the optical module to determine whether the estimated initial mole fractions and the calculated component densities of the one or more components of the gas are representative of actual mole fractions and component densities of the one or more components of the gas.
20. The logging tool of claim 19 , wherein the gas comprises hydrogen (H 2 ), carbon dioxide (CO 2 ), carbon monoxide (CO), methane (CH 4 ), ethane (C 2 H 6 ), propane (C 3 H 8 ), butane (C 4 H 10 ), pentane (C 5 H 12 ), hexane (C 6 H 14 ), heptane (C 7 H 16 ), octane (C 8 H 18 ), nonane (C 9 H 20 ), decane (C 10 H 22 ), hydrogen sulfide (H 2 S), nitrogen (N 2 ), or some combination thereof.