Direct steam generator degassing
Systems and methods generate steam mixed with desired non-condensable gas concentrations using a direct steam generator. Injecting the steam into a reservoir may facilitate recovering hydrocarbons from the reservoir. Cooling an output of the direct steam generator produces water condensate, which is then separated from the non-condensable gas, such as carbon dioxide. Reducing pressure of the condensate subsequently heated by cross-exchange with effluent of the direct steam generator regenerates the steam with the carbon dioxide removed for the injection.
1. A method of recovering hydrocarbons with steam, comprising:
vaporizing water by direct contact of the water with combustion products to produce a resulting fluid including the steam and a non-condensable gas;
condensing the fluid to provide a mixture of the non-condensable gas and a water condensate, wherein the water condensate comprises a liquid phase;
separating a gas phase with the non-condensable gas from the liquid phase with the water condensate;
regenerating the steam from the water condensate by reducing pressure and then heating the condensate in a heat exchanger; and
injecting the steam formed from the water condensate into a formation for recovery of the hydrocarbons.
2. The method of claim 1 , wherein the condensing of the fluid includes passing the fluid through the heat exchanger and then passing the fluid through a cooling unit.
3. The method of claim 1 , wherein the reducing of the pressure includes passing the condensate through at least one of an orifice and a throttling valve.
4. The method of claim 1 , further comprising vaporizing a liquid component that is separated from the steam following the reducing of the pressure and the heating in the heat exchanger.
5. The method of claim 1 , wherein the gas phase with the non-condensable gas is conveyed to a sequestration site distinct from the formation with the hydrocarbons.
6. The method of claim 1 , wherein the fluid is at a first pressure between 10,000 and 14,500 kilopascals (kPa) and the steam that is injected into the formation is at a second pressure between 5500 and 10,000 kPa.
7. The method of claim 1 , wherein the separating of the gas phase results in the steam that is injected having less than ten percent of the non-condensable gas from the fluid.
8. The method of claim 1 , wherein the mixture of the non-condensable gas and the water condensate prior to separation is at least eighty percent liquid by weight.
9. The method of claim 1 , wherein the mixture of the non-condensable gas and the water condensate prior to separation is between eighty-three and ninety-three percent liquid by weight.
10. The method of claim 1 , wherein the vaporizing of the water provides the steam that is superheated.
11. A system for recovering hydrocarbons with steam, comprising:
a steam generator in which water vaporizes by direct contact with combustion products to produce a resulting fluid including the steam and a non-condensable gas;
a heat exchanger coupled to receive the fluid from the steam generator to form a mixture of the non-condensable gas and a water condensate, wherein the water condensate comprises a liquid phase;
a separation vessel coupled to the heat exchanger for removing a gas phase with the non-condensable gas from the liquid phase with the condensate;
a pressure reducer coupled between an outlet for the condensate from the vessel and the heat exchanger to regenerate the steam from the water condensate; and
at least one injection well coupled to the pressure reducer for introducing the steam formed from the water condensate into a formation with the non-condensable gas removed.
12. The system of claim 11 , wherein the heat exchanger includes a cooling unit.
13. The system of claim 11 , wherein the pressure reducer is at least one of an orifice and a throttling valve.
14. The system of claim 11 , further comprising a recycle conduit coupled to supply the steam generator with a liquid component separated from the regenerated steam.
15. The system of claim 11 , further comprising a sequestration site distinct from the formation with the hydrocarbons and where the gas phase with the non-condensable gas is conveyed.
16. The system of claim 11 , wherein the steam generator operates at a first pressure between 10,000 and 14,500 kilopascals (kPa) and the pressure reducer is configured to provide the steam that is injected into the formation at a second pressure between 5500 and 10,000 kPa.
17. A method of recovering hydrocarbons with steam, comprising:
vaporizing water by direct contact of the water with combustion products to produce a resulting fluid including the steam and a non-condensable gas;
treating the fluid to provide a mixture of the non-condensable gas and a water condensate, wherein the water condensate comprises a liquid phase;
separating a gas phase with the non-condensable gas from the liquid phase with the water condensate;
regenerating the steam from the water condensate by reducing pressure and then heating the water condensate in a heat exchanger; and
injecting the steam formed from the water condensate into a formation for recovery of the hydrocarbons.
18. The method of claim 17 , wherein the separating results in the steam at the second pressure having less than ten percent of the non-condensable gas from the fluid.
19. The method of claim 17 , wherein a mixture of the non-condensable gas and the water condensate prior to the separating is between eighty-three and ninety-three percent liquid by weight.
20. The method of claim 17 , wherein reducing pressure of the condensate comprises a pressure reducer comprising at least one of an orifice and a throttling valve.