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This invention consists of a method to enable methane recovery from hydrate reservoirs. The invention, in particular, relates to a Saltwater Hydrate Extraction Process (SHEP) in which high salinity water is injected into a hydrate reservoir into a lower horizontal well to promote and control gas production by hydrate decomposition to an upper deviated production well.

Titel:	In Situ Process to Recover Methane Gas from Hydrates
Autor/in / Beteiligte Person:	Bunio, Gary ; Gates, Ian Donald ; Wang, Jacky
Link:	View record in USPTO Patent Applications (Volltext)
Veröffentlichung:	2012
Medientyp:	Patent
Sonstiges:	Nachgewiesen in: USPTO Patent Applications Sprachen: English Document Number: 20120145388 Publication Date: June 14, 2012 Appl. No: 13/314344 Application Filed: December 08, 2011 Assignees: MGM Energy Corp. (Calgary, CA) Claim: 1. A method to recover methane gas from an underground hydrate reservoir that has been penetrated by injection and production wells, the method comprising the steps of: a) drilling a saline water injection well proximate the base of the hydrate reservoir; and b) drilling a substantially non parallel production well that at some location along its length is within 1 to 10 m from a part of the injection well; and c) initially injecting saline water into the production well which creates a depletion chamber between the injection and production wells; and d) varying the injection procedure for the saline water, for example preferably varying at least one of injection pressure, injection rate, temperature, or salinity, to propagate a depletion chamber in the hydrate formation resulting from hydrate decomposition; and e) extraction of gas and water from the depletion chamber through the production well. Claim: 2. The method of claim 1 further comprising the step of monitoring and varying the injection pressure and temperature to enhance propagation of the depletion chamber and extraction of gas. Claim: 3. The method of claim 1 further comprising the step of monitoring and changing the extraction rate to alter the pressure and temperature of the depletion chamber, its propagation and extraction of gas. Claim: 4. The method of claim 1 further comprising the step of monitoring and changing the salinity of the injected water to enhance propagation of the depletion chamber and extraction of gas. Claim: 5. A method according to any one of claims 1-4 where an additional step is implemented where injection is stopped and gas is continually extracted from the reservoir. Claim: 6. A method for recovery of methane gas from an underground hydrate formation comprising establishing of at least one pair of generally non parallel wells: a lower injection well and an upper production well, wherein the injection well delivers saline water to the formation and the production well recovers gas and water from the formation. Claim: 7. The method of claim 6 wherein a depletion chamber is created as a result of the operation of the well pair, starting at the point of the minimal distance between the wells. Claim: 8. The method of claim 6 or 7 wherein the injection well extends horizontally proximate a lower part of the hydrate formation and the production well extends above the injection well, while the vertical distance between the injection well and the production well vary from a minimal distance of 1 to 10 meters to a maximum distance of the thickness of the hydrate formation. Claim: 9. The method of claim 8 wherein the heel of the production well is located proximate to the top of the hydrate deposit and its toe is located 1 to 10 meters above the toe of the injection well, while the production well extends between its heel and its toe at an angle to the injection well. Claim: 10. The method of claim 8 wherein the heel of the production well is located 1 to 10 meters above the heel of the injection well and its toe is located proximate the top of the hydrate deposit above the toe of the injection well, while the production well extends between its heel and its toe at an angle to the injection well. Claim: 11. The method of claim 8 wherein the heel of the production well is located above the heel of the injection well at a distance between 1 meter up to the top of the hydrate deposit, and the toe of the production well is located above the toe of the injection well at a distance selected from 1 meter up to the top of the hydrate deposit, the production well extends between its heel and its toe substantially non parallel to the injection well, and there is at least one intermediate segment of the production well positioned between the heel and the toe which is located 1 to 10 meters from the injection well. Claim: 12. The method of claim 11 wherein the angle between the production well and the injection well varies between the head of the well to the toe of the well, therein there is one angle before the intermediate point and another angle beyond it. Claim: 13. The method of claim 6 or 7 wherein heated saline water is injected into the injection well and the produced gas and water are retrieved from the production well. Claim: 14. The method of claim 13 wherein in one step of the process the output of the production well is shut, and only the injection well is operable, while in an another step the inlet to the injection well is shut, and only the production well is operable. Claim: 15. A process for extracting methane gas from a hydrate deposit, the process comprising the following steps: drilling two generally non parallel wells: a lower injection well and an upper production well, injecting into the lower well heated saline water to create a depletion chamber, waiting for separation of the gas and water phases, extracting of the gas and water from the deposit, separating the gas from the water, and reusing the water for further injection. Claim: 16. The process in claim 15 wherein the lower well extends substantially horizontally at the bottom of the hydrate deposit, and the upper well extends at an angle to the lower well, and the vertical distance varies from 1 meter up to the top of the hydrate deposit, and in this way gas can be extracted from any location in the depletion chamber. Claim: 17. A system for extracting methane gas from a hydrate deposit, the system comprising an injection well, a production well, a water injecting unit, and a gas collecting unit, said injection well extending vertically from the injection point toward the bottom of the hydrate deposit and then extends horizontally along the hydrate deposit's bottom, said production well extends vertically from the ground to the top of the hydrate deposit and then extending in a non parallel direction above the injection well; at least one segment of the production well being located proximate the injection well and the balance of the production well being positioned in the hydrate deposit remote from the injection well; the water injecting unit being attached to the injection well and the gas collecting unit being attached to the production well. Claim: 18. The system, process or method of claim 1, 6, 15 or 17 further comprising a movable packer in the production well. Current U.S. Class: 166/275 Current International Class: 21

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In Situ Process to Recover Methane Gas from Hydrates