Pressure-balanced oil recovery process for water productive oil shale

• US 4,148,359 A
• Filed: 01/30/1978
• Issued: 04/10/1979
• Est. Priority Date: 01/30/1978
• Status: Expired due to Term

• Current Assignee: Shell Oil Company (Shell Plc)
• Original Assignee: Shell Oil Company (Shell Plc)
• Inventors: Koci, Paul F., Laumbach, Dallas D.
• Primary Examiner(s): Novosad, Stephen J.
• Application Number:
  US05/873,338
• Time in Patent Office: 435 Days
• Field of Search: 166/261, 166/260, 166/272, 166/256, 166/257, 166/303, 166/250, 166/252, 166/251, 166/306
• US Class Current: 166/261
• CPC Class Codes: E21B 43/24 using heat, e.g. steam injection
• CPC Class Codes: E21B 43/243 Combustion in situ

Abstract

In producing shale oil from a water-productive leached zone of a subterranean oil shale the reservoir pressure is counterbalanced to restrict water production. A generally vertical heated channel is formed by injecting steam into a lower location while producing fluid from an upper location until a steam zone extends substantially between the locations. Oil shale is pyrolyzed within the heated channel by flowing gaseous fluid, which contains noncondensable components and is heated to an oil shale pyrolyzing temperature, upward through the channel. Shale oil is recovered from the fluid flowing upward through the channel while the composition, pressure and rate of flow of that fluid are adjusted to maintain a selected ratio between its oil phase and aqueous phase components.

Claims

1. A process for producing shale oil from a subterranean oil shale formation, which comprises:

providing means for injecting fluids into and producing fluids from an oil shale formation by opening at least one well into fluid communication with a subterranean leached-zone oil shale formation having a composition at least substantially equivalent to those portions of oil shale formations encountered in the Piceance Creek Basin of Colorado which contain networks of relatively permeable interconnected water-filled and water-productive flow channels formed by natural fracturing or leaching of the formation;

providing a generally vertical heated channel extending through said formation between an injection location underlying a production location by injecting steam into the lower location while producing fluid from the higher location and adjusting the composition, pressure, flow rate and volume of the injected and produced fluid to enhance water removal, drying and preheating of the oil shale so that a substantially steam-filled zone is extended from each injection location to at least near each production location;

injecting a gaseous fluid which contains effectively noncondensible gaseous components and is heated to an oil shale pyrolyzing temperature into the lower portion of the heated channel so that oil shale is pyrolyzed by hot fluid flowing upward through the channel; and

producing shale oil from an upper portion of the heated channel while adjusting the composition, pressure and flow rate of the injected and produced fluid to restrict the production of water by counterbalancing the reservoir pressure and to maintain a ratio of oil-phase to water-phase components of at least about 0.10 within the produced field.

2. The process of claim 1 in which the production location is higher than the injection location by about 150-750 feet and is spaced laterally from the injection location by about 0-500 feet, with the respective injection and production locations being within the lower and upper 10% of the oil shale formation.

3. The process of claim 1 in which the steam injected to form the heated channel has a temperature of from about 400°

-500°

F. and the fluid injected to pyrolyze oil shale within the heated channel is flowed through the channel at a temperature of from about 500°

-1500°

F. at a pressure exceeding that of the reservoir fluid pressure by from about 50-2500 psi.

4. The process of claim 1 in which the fluid injected to pyrolyze oil shale within the heated channel is preheated at a surface location or within a well bore prior to its injection into the channel.

5. The process of claim 1 in which the fluid injected to pyrolyze the oil shale within the heated channel is heated by an underground combustion within that channel.

6. The process of claim 5 in which the gas injected to support the underground combustion is a mixture of combustion-supporting gas and inert effectively noncondensible gas.

7. The process of claim 6 in which water is contained in the gas injected to provide the underground combustion.

8. The process of claim 6 in which the underground combustion is controlled to maintain a combustion zone pressure and temperature of about 1,000 psi and 1000°

F.