Method of developing subsurface freeze zone

• US 7,647,971 B2
• Filed: 12/23/2008
• Issued: 01/19/2010
• Est. Priority Date: 10/13/2006
• Status: Expired due to Fees

• Current Assignee: Exxonmobil Upstream Research Company (Exxon Mobil Corporation)
• Original Assignee: Exxonmobil Upstream Research Company (Exxon Mobil Corporation)
• Inventors: Kaminsky, Robert D.
• Primary Examiner(s): Suchfield; George
• Application Number:
  US12/343,109
• Publication Number:
  US 20090101348A1
• Time in Patent Office: 392 Days
• Field of Search: None
• US Class Current: 166/302
• CPC Class Codes: E21B 36/001 Cooling arrangements
• CPC Class Codes: E21B 41/0064 Carbon dioxide sequestration storing fluids in porous layers B65G5/005
• CPC Class Codes: Y02C 20/40 of CO2

Abstract

A method of lowering the temperature of a subsurface formation, e.g., comprising oil shale, includes injecting a cooling fluid under pressure into a wellbore. The wellbore is completed at or below a depth of the subsurface formation, and the wellbore includes a bore formed through the subsurface formation defining a diameter. The cooling fluid comprises a slurry having particles of frozen material. The cooling fluid is circulated across the formation in order to lower the temperature of at least a portion of the formation to a point that is at or below the freezing point of water.

Claims

1. A method of lowering the temperature of a subsurface formation, comprising:

(a) injecting a cooling fluid under pressure into a wellbore, the wellbore being completed at or below a depth of the subsurface formation, and the wellbore having a bore formed through the subsurface formation defining a diameter, wherein the cooling fluid comprises a slurry having particles of frozen material;

(b) circulating the cooling fluid across the formation in order to lower the temperature of at least a portion of the formation to a point that is at or below the freezing point of water; and

(c) injecting low salinity water into at least a portion of the subsurface formation to reduce the natural salinity of the in situ water and to raise the freezing temperature of the in situ water.

2. The method of claim 1, wherein the cooling fluid defines a partially frozen alcohol-water mixture, a partially frozen glycol water mixture, a salt water mixture, or combinations thereof.

3. The method of claim 1, wherein the particles are less than 50 microns in size.

4. The method of claim 1, wherein the cooling fluid is chilled below ambient air temperature prior to injection into the wellbore.

5. The method of claim 1, wherein the subsurface formation comprises in situ water, and the cooling fluid cools the subsurface formation sufficient to freeze at least a portion of the in situ water.

6. The method of claim 1, wherein the wellbore comprises:

an elongated tubular member, the elongated tubular member comprising a U-tube comprising a downward portion through which the cooling fluid flows to the subsurface formation, and an upward portion through which the cooling fluid flows back to the surface.

7. The method of claim 6, wherein:

injecting a cooling fluid creates a downward flow of fluid into the wellbore, and an upward flow of fluid out of the wellbore; and

a heat transfer coefficient between the upward and downward flows is less than 50 W/m²·

C.

8. The method of claim 6, wherein the heat transfer coefficient between the upward and downward flows below the first expansion valve is less than 25 W/m²·

C.

9. A method of lowering the temperature of a subsurface formation, comprising:

(a) injecting a cooling fluid under pressure into a wellbore, the wellbore being completed at or below a depth of the subsurface formation, and the wellbore having a bore formed through the subsurface formation defining a diameter, wherein the cooling fluid comprises a slurry having particles of frozen material; and

(b) circulating the cooling fluid across the formation in order to lower the temperature of at least a portion of the formation to a point that is at or below the freezing point of water;

wherein the wellbore comprises;

an elongated tubular member, the elongated tubular member comprising a U-tube comprising a downward portion through which the cooling fluid flows to the subsurface formation, and an upward portion through which the cooling fluid flows back to the surface; and

the downward portion is insulated above the subsurface formation.

10. The method of claim 9, wherein the cooling fluid defines a partially frozen alcohol-water mixture, a partially frozen glycol water mixture, a salt water mixture, or combinations thereof.

11. The method of claim 9, wherein the particles are less than 50 microns in size.

12. The method of claim 9, wherein the cooling fluid is chilled below ambient air temperature prior to injection into the wellbore.

13. The method of claim 9, wherein the subsurface formation comprises in situ water, and the cooling fluid cools the subsurface formation sufficient to freeze at least a portion of the in situ water.

14. The method of claim 9, further comprising:

injecting low salinity water into at least a portion of the subsurface formation to reduce the natural salinity of the in situ water and to raise the freezing temperature of the in situ water.

15. The method of claim 9, wherein:

injecting a cooling fluid creates a downward flow of fluid into the wellbore, and an upward flow of fluid out of the wellbore; and

a heat transfer coefficient between the upward and downward flows is less than 50 W/m²·

C.

16. The method of claim 15, wherein the heat transfer coefficient between the upward and downward flows is less than 25 W/m²·

C.