Gas transfer energy recovery and effervescence prevention apparatus and method
원문보기
IPC분류정보
국가/구분
United States(US) Patent
등록
국제특허분류(IPC7판)
F01K-025/06
F01K-025/00
출원번호
US-0125161
(2002-04-18)
발명자
/ 주소
Speece, Richard E.
출원인 / 주소
Eco Oxygen Technologies, LLC.
대리인 / 주소
Gridley, Doreen J.St. Peter, Rachel L.Ice Miller
인용정보
피인용 횟수 :
5인용 특허 :
152
초록▼
A gas transfer system and method for dissolving at least one gas into a liquid. The system includes a gas transfer vessel also known as a reactor. A liquid inlet feed is connected to the reactor for transferring the liquid into the reactor. A gas inlet is connected to the reactor for feeding the gas
A gas transfer system and method for dissolving at least one gas into a liquid. The system includes a gas transfer vessel also known as a reactor. A liquid inlet feed is connected to the reactor for transferring the liquid into the reactor. A gas inlet is connected to the reactor for feeding the gas into the reactor. An outlet is connected to the reactor for transferring the liquid with at least some of the gas therein away from the reactor. The system also includes a feed pump connected to the inlet feed to pressurize the contents of the inlet feed and the reactor, and a regenerative turbine connected to the feed pump and to the outlet. The various embodiments of the gas transfer system use pressurization in the gas transfer vessel to enhance gas transfer therein, minimize the net energy consumption, and retain highly supersaturated dissolved gas in solution. Some embodiments further help to reduce effervescence loss. The method of the present invention utilizes the system of the present invention and operates the feed pump and regenerative turbine to accomplish these advantages.
대표청구항▼
A gas transfer system and method for dissolving at least one gas into a liquid. The system includes a gas transfer vessel also known as a reactor. A liquid inlet feed is connected to the reactor for transferring the liquid into the reactor. A gas inlet is connected to the reactor for feeding the gas
A gas transfer system and method for dissolving at least one gas into a liquid. The system includes a gas transfer vessel also known as a reactor. A liquid inlet feed is connected to the reactor for transferring the liquid into the reactor. A gas inlet is connected to the reactor for feeding the gas into the reactor. An outlet is connected to the reactor for transferring the liquid with at least some of the gas therein away from the reactor. The system also includes a feed pump connected to the inlet feed to pressurize the contents of the inlet feed and the reactor, and a regenerative turbine connected to the feed pump and to the outlet. The various embodiments of the gas transfer system use pressurization in the gas transfer vessel to enhance gas transfer therein, minimize the net energy consumption, and retain highly supersaturated dissolved gas in solution. Some embodiments further help to reduce effervescence loss. The method of the present invention utilizes the system of the present invention and operates the feed pump and regenerative turbine to accomplish these advantages. ger structures in said chamber interior, to receive heat transferred from the exhaust gas, said structures providing means for received pressurized liquid for flow in different paths there-through, and developing vapor streams at different pressures and temperatures without use of boiler drums, c) the structures having outlets to communicate with a vapor driven turbine or turbines having inlet ports at different inlet fluid pressure zones, c) and wherein said structures extend generally longitudinally in the chamber, and each intercepting a different fraction of the hot exhaust gas. 12. A hot exhaust heat recovery system comprising, in combination a) means for forming a chamber having inlet and chamber interior, b) separate heat exchanger structures in said chamber interior, to receive heat transferred from the exhaust gas, said structures providing means for receiving pressurized liquid for flow in different paths there-through, and developing vapor streams at different pressures and temperatures without use of boiler drums, c) the structures having outlets to communicate with a vapor driven turbine or turbines having inlet ports at different inlet fluid pressure zones, d) and wherein said structures have different longitudinal lengths and widths, in said chamber interior, and have coils along their lengths. 13. A hot exhaust gas heat recovery system comprising, in combination a) a structure forming a chamber having inlet and outlet porting for flow through of hot exhaust gas, in the chamber interior, b) separate heat exchanger structures in separate zones which are sequential in the direction of flow of the exhaust gases, said heat exchanger structures receiving liquid or vapor for flow in different paths there-through, to develop vapor streams at different pressures and temperatures without use of boiler drums, c) wherein said heat exchanger structures are located to each intercept a different fraction of the hot gas stream to provide the required heat to produce the required condition at the exist of the heat exchanger structures, d) wherein said heat exchanger structures have outlets to communicate with a vapor driven turbine or turbines having inlet ports requiring different inlet fluid pressures wherein said inlet fluid pressures are at successively lower pressures corresponding to the pressures produced by the separate heat exchanger structures. 14. The combination of claim 13 wherein there are more than one heat exchanger structure in each zone and extending longitudinally in the zone, each intercepting a different fraction of the hot exhaust gas. 15. The combination of claim 13 wherein said structures have different longitudinal lengths and widths in said chamber interior and have coils or plate-fin heat exchanger passages along their length. d fluid having an increased heat content. 3. The method as recited in claim 1 wherein the creation of the hot dry rock reservoir comprises injecting the fluid into a packed off interval of an openhole wellbore and thence into a deep region of hot dry rock. 4. The method as recited in claim 1 wherein the hot dry rock reservoir is at a depth in the range of from about 1,000 feet to about 30,000 feet. 5. The method as recited in claim 1 wherein the hot dry rock of the hot dry rock reservoir has a temperature in the range from about 120° C. to about 1,000° C. 6. The method as recited in claim 5 wherein the temperature of the hot dry rock of the hot dry rock reservoir has a temperature in the range of from about 150° C. to about 500° C. 7. The method as recited in claim 1 wherein the hot dry rock of the hot rock reservoir comprises rock selected from the group consisting of igneous, metamorphic and sedimentary rock. 8. The method as recited in claim 1 wherein the fluid is injected at a pressure in the range from about 1,000 psi to about 15,000 psi. 9. The method as recited in claim 1 wherein the fluid is injected through an open wellbore for an injection period in the range from about a few hours to several months. 10. The method as recited in claim 1 wherein the fluid is injected through an open wellbore for an injection period in the range from about 1 week to about three months. 11. The method as recited in claim 1 wherein the fluid is injected at a rate in the range from about 20 to 60 kilograms per second. 12. A method of extracting geothermal energy from an underground hot dry rock reservoir, comprising the steps of: (a) injecting fluid consisting essentially of carbon dioxide into an underground hot dry rock reservoir, the fluid carbon dioxide comprising fluid in the supercritical phase or carbon dioxide fluid that is transformed into the supercritical phase by the hot dry rock; (b) allowing the fluid to absorb heat from the hot dry rock of the hot dry rock reservoir and thereby increase the heat content of the fluid; (c) removing at least a portion of the fluid having an increased heat content from the underground hot dry rock reservoir; and (d) extracting heat from the portion of fluid having an increased heat content. 13. The method as recited in claim 12 wherein the fluid is injected into the underground reservoir region through at least one injection well. 14. The method as recited in claim 12 wherein the fluid is injected into the underground reservoir region through a plurality of injection wells. 15. The method as recited in claim 12 wherein the fluid is conducted from said reservoir region through at least one production well. 16. The method as recited in claim 12 wherein the fluid is conducted from the reservoir region through a plurality of production wells. 17. The method as recited in claim 12 wherein after the step of heat extraction the fluid is circulated back into the underground reservoir. 18. The method as recited in claim 12 wherein the fluid is conducted from said reservoir region by pumping and thermal siphoning. 19. The method as recited as recited in claim 12 wherein the hot dry rock reservoir comprises rocks selected from the group consisting of igneous, metamorphic and sedimentary rocks. 20. The method as recited in claim 12 wherein the temperature of the hot dry rock reservoir is in the range from about 120° C. to about 1,000° C. 21. The method as recited in claim 12 wherein the temperature of the hot dry rock reservoir is in the range from about 150° C. to about 500° C. 22. The method as recited in claim 12 wherein the hot dry rock reservoir is at a depth in the range from about 1,000 feet to about 30,000 feet. 23. The method as recited in claim 12 wherein the fluid is injected at a pressure in the range from about 1,000 psi to about 15,000 psi. 24. The method as recited in claim 12 further comprising removing water from the portion of fluid that has been removed from the reservo
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