In-situ process to produce hydrogen-bearing gas from underground petroleum reservoirs
Implementations relate to treatment of a petroleum reservoir to produce a hydrogen-bearing gas. Implementations may include methods and systems for processing a reservoir to generate hydrogen in-situ and produce a large fraction of the generated hydrogen to the surface. Processing the reservoir may include injecting oxygen into the reservoir to enable combustion within the reservoir to create heat and carbon monoxide in the reservoir. The heat may generate steam from both boiling of in-situ formation water and steam generated from the oxidation reactions. The generated heat may enable gasification, steam reforming, and aquathermolysis reactions and both the heat and carbon monoxide enables the water-gas shift reaction. Each such reaction may generate hydrogen within the reservoir.
1. A method for treating a reservoir to recover a hydrogen-bearing gas, comprising:
providing a well passing through a surface of the earth into a reservoir of a formation;
in a pre-heat stage:
pre-heating the reservoir by injecting a heating fluid into the well; and
producing pre-production fluids from the reservoir to yield a depletion chamber within the reservoir;
in an injection stage:
injecting an oxygen-bearing gas via the well and the depletion chamber into the reservoir to yield an in-situ reactor zone where hydrocarbons including oil and gas are combusted to generate heat, steam, and carbon oxide gas components;
maintaining conditions for hydrogen-generating reactions, including one or more of gasification reactions, steam-reforming reactions, water-gas shift reactions, and aquathermolysis reactions to occur in the reservoir, thereby generating hydrogen; and
stopping injection of the oxygen-bearing gas;
in a soak stage:
shutting in the well; and
allowing remaining oxygen in the reservoir to be consumed and the hydrogen-generating reactions to continue, thereby continuing to generate hydrogen; and
in a production stage:
producing production fluids via the well to the surface including a hydrogen-bearing gas comprising the generated hydrogen;
continuing production through the well until a production rate of the hydrogen-bearing gas has dropped below a target rate; and
shutting in the well.
2. The method of claim 1 , wherein the injection stage, the soak stage, and the production stage are repeated in one or more cycles.
3. The method of claim 1 , wherein the generated hydrogen is maintained in a portion of the formation proximate the well during the soak stage, such that the generated hydrogen is readily producible from the portion of the formation proximate the well.
4. The method of claim 1 , wherein a temperature of the oxygen-bearing gas is elevated prior to injection into the reservoir.
5. The method of claim 1 , wherein the well is one of a plurality of wells passing through the surface into the reservoir and an operation of the plurality of wells is coordinated to control a pressure within the reservoir, thereby enhancing the production of the hydrogen-bearing gas from one or more of the wells.
6. The method of claim 5 , wherein one or both of the heating fluid or oxygen-bearing gas is injected into one or more well of the plurality of wells to form a high pressure connected zone within the reservoir.
7. The method of claim 6 , wherein producing production fluids from one or more well of the plurality of wells forms a low pressure connected zone within the reservoir, thereby creating a pressure gradient between the high pressure connected zone and the low pressure connected zone, thereby enhancing hydrogen production from the reservoir.
8. The method of claim 5 , wherein upon establishing fluid communication between at least two wells of the plurality of wells, one of the two wells of the plurality of wells is configured for continuous injection of the heating fluid or the oxygen-bearing gas and the other of the two wells of the plurality of wells is configured for continuous production of the production fluids.
9. The method of claim 1 , wherein the oxygen-bearing gas comprises an oxidant, nitrous oxide, or hydrogen peroxide.
10. The method of claim 1 , wherein a thermocouple configured to monitor a temperature of the well or fluids therein is disposed within the well.
11. The method of claim 1 , wherein the heating fluid is injected into the well until a temperature of the well is at least a pre-heat temperature.
12. The method of claim 11 , wherein the pre-heat temperature is equal to or greater than 40% of a temperature of the heating fluid.
13. The method of claim 1 , wherein the injection of the oxygen-bearing gas is stopped when a measured temperature reaches a running temperature.
14. The method of claim 13 , wherein the running temperature is the lesser of 400° C. and 200° C. above a temperature of the heating fluid.
15. The method of claim 1 , wherein the soak stage includes allowing the remaining oxygen in the reservoir to be consumed and the hydrogen-generating reactions to continue until a temperature of the well decreases to a soak temperature.
16. The method of claim 15 , wherein the soak temperature is the higher of 300° C. or 50° C. below a peak temperature of the well during the injection stage.
17. The method of claim 1 , wherein the injection of the oxygen-bearing gas is stopped when a pressure of the well reaches a peak pressure.
18. A system for treating a reservoir to recover a hydrogen-bearing gas, comprising:
a well passing through a surface of the earth into a reservoir of a formation; and
a heating fluid source in fluid communication with the well and configured to supply a heating fluid to the well;
wherein the system is configured to perform a method comprising:
in a pre-heat stage:
pre-heat the reservoir by injecting a heating fluid into the well; and
produce pre-production fluids from the reservoir to yield a depletion chamber within the reservoir;
in an injection stage:
inject an oxygen-bearing gas via the well and the depletion chamber into the reservoir to yield an in-situ reactor zone where hydrocarbons including oil and gas are combusted to generate heat, steam, and carbon oxide gas components;
maintain conditions for hydrogen-generating reactions, including one or more of gasification reactions, steam-reforming reactions, water-gas shift reactions, and aquathermolysis reactions to occur in the reservoir, thereby generating hydrogen; and
stop injection of the oxygen-bearing gas;
in a soak stage:
shut in the well; and
allow remaining oxygen in the reservoir to be consumed and the hydrogen-generating reactions to continue, thereby continuing to generate hydrogen; and
in a production stage:
produce production fluids via the well to the surface including a hydrogen-bearing gas comprising the generated hydrogen;
continue production through the well until a production rate of the hydrogen-bearing gas has dropped below a target rate; and
shut in the well.
19. The system of claim 18 , wherein the well comprises a vertical well, a deviated well, a horizontal well, or a multilateral well.
20. A system for treating a reservoir to recover a hydrogen-bearing gas, comprising:
a plurality of wells, each well passing through a surface of the earth into a reservoir of a formation and configured for coordinated operation; and
a heating fluid source in fluid communication with the well and configured to supply a heating fluid to the well;
wherein the system is configured to perform a method comprising, with one or more well of the plurality of wells:
in a pre-heat stage:
pre-heat the reservoir by injecting a heating fluid into the well; and
produce pre-production fluids from the reservoir to yield a depletion chamber within the reservoir;
in an injection stage:
inject an oxygen-bearing gas via the well and the depletion chamber into the reservoir to yield an in-situ reactor zone where hydrocarbons including oil and gas are combusted to generate heat, steam, and carbon oxide gas components;
maintain conditions for hydrogen-generating reactions, including one or more of gasification reactions, steam-reforming reactions, water-gas shift reactions, and aquathermolysis reactions to occur in the reservoir, thereby generating hydrogen; and
stop injection of the oxygen-bearing gas;
in a soak stage:
shut in the well; and
allow remaining oxygen in the reservoir to be consumed and the hydrogen-generating reactions to continue, thereby continuing to generate hydrogen; and
in a production stage:
produce production fluids via the well to the surface including a hydrogen-bearing gas comprising the generated hydrogen;
continue production through the well until a production rate of the hydrogen-bearing gas has dropped below a target rate; and
shutting in the well;
wherein the heating fluid or the oxygen-bearing gas is injected to form a high pressure connected zone within the reservoir; and
wherein producing production fluids forms a low pressure connected zone within the reservoir, thereby creating a pressure gradient between the high pressure connected zone and the low pressure connected zone and enhancing hydrogen production from the reservoir.