Granted Patent B2

US 12,595,936 · App. 18/630,249 · Granted Apr 7, 2026

Inventor: William W. Fleckenstein (Lakewood, CO)

Assignee: Colorado School of Mines

F24T10/30E21B43/26F03G4/023

Abstract

Claims (41)

1 . A method of harvesting a fluid from a subterranean formation, comprising:

positioning a plurality of sleeves in an injection wellbore that extends into the subterranean formation, the plurality of sleeves each being spaced apart within the injection wellbore and threadably connected to a casing string, each sleeve of the plurality of sleeves being selectively actuatable between a first position, a second position, and a third position, wherein at least one of the plurality of sleeves are encased in cement;

fracturing the subterranean formation in a plurality of locations proximate to the plurality of sleeves to enhance a plurality of fluid pathways between the injection wellbore and at least one producing wellbore that extends into the subterranean formation, wherein each location of the plurality of locations corresponds to a respective sleeve of the plurality of sleeves, wherein when the respective sleeve is in a respective one of the first position, the second position, and the third position a fluid pathway of the plurality of fluid pathways extends from the respective sleeve to the at least one producing wellbore;

injecting a fluid down the injection wellbore at a first temperature, wherein the fluid harvests geothermal energy from the subterranean formation as the fluid flows through a respective fluid pathway of the plurality of fluid pathways to the at least one producing wellbore; and

producing a heated fluid from the at least one producing wellbore at a second temperature higher than the first temperature.

2 . The method of claim 1 , further comprising:

monitoring the rate of fluid flow of the fluid; and

selectively setting at least one sleeve of the plurality of sleeves to a respective third position to regulate the fluid flow of the fluid between the injection wellbore and the at least one producing wellbore, thereby optimizing a thermal efficiency and a temperature gain between the fluid and the heated fluid.

3 . The method of claim 1 , further comprising:

monitoring the rate of fluid flow of the fluid; and

selectively opening at least one sleeve of the plurality of sleeves by setting it to a respective first position to start fluid flow of the fluid through the at least one sleeve between the injection wellbore and the at least one producing wellbore, thereby optimizing a thermal efficiency and a temperature gain between the fluid and the heated fluid.

4 . The method of claim 1 , further comprising:

monitoring the rate of fluid flow of the fluid; and

selectively closing at least one sleeve of the plurality of sleeves by setting it to a respective second position to stop fluid flow of the fluid through the at least one sleeve between the injection wellbore and the at least one producing wellbore, thereby optimizing a thermal efficiency and a temperature gain between the fluid and the heated fluid.

5 . The method of claim 1 , further comprising:

monitoring a fluid pressure drop at one or more of the injection wellbore and the at least one producing wellbore to determine which sleeve of the plurality of sleeves should be in a respective first position, a respective second position, or a respective third position, thereby optimizing fluid flow between the injection wellbore and the at least one producing wellbore.

6 . The method of claim 1 , wherein at least one sleeve of the plurality of sleeves is actuated from a respective second position to a respective first position through a respective third position by pumping a ball down the injection wellbore into a catch assembly of the at least one sleeve of the plurality of sleeves at a first fluid pressure.

7 . The method of claim 6 , wherein the catch assembly is configured to pass the ball through the catch assembly of the at least one sleeve of the plurality of sleeves when a second fluid pressure that is higher than the first fluid pressure is applied to the ball.

8 . The method of claim 6 , wherein a diameter of the ball is configured to decrease based on one or more of time or a chemistry of the fluid, wherein after the diameter of the ball decreases by a predetermined amount, the ball passes through the catch assembly located on the at least one sleeve of the plurality of sleeves.

9 . The method of claim 1 , wherein at least one sleeve of the plurality of sleeves is actuated from a respective second position to a respective first position through a respective third position with at least one of a downhole tool or downhole tractor selectively positioned with tubing and driven with electrical energy or hydraulic energy.

10 . The method of claim 1 , further comprising:

fracturing a particular location of the plurality of locations in the subterranean formation by engaging the respective sleeve of the plurality of sleeves when the respective sleeve is in the respective first position to enhance the conductivity of the particular location of the plurality of sleeves.

11 . The method of claim 1 , further comprising:

measuring, via a control system including one or more sensors, an amount of energy harvested within the heated fluid from the subterranean formation; and

selectively actuating at least one sleeve of the plurality of sleeves between any two of a respective first position, a respective second position, and a respective third position to optimize a temperature differential between the first temperature of the fluid injected into the injection wellbore and the second temperature of the heated fluid produced by the at least one producing wellbore.

12 . The method of claim 11 , wherein the control system further comprises a pressure monitoring system operable to:

determine a rate of fluid flow of the heated fluid through one or more stages in the subterranean formation defined by fractures associated with one or more locations of the plurality of locations; and

selectively actuating at least one sleeve of the plurality of sleeves between any two of a respective first position, a respective second position, and a respective third position to optimize at least one of an amount of the fluid being injected into the injection wellbore, an amount of the heated fluid produced by the at least one producing wellbore, the rate of fluid flow for the fluid being injected into the injection wellbore, and the rate of fluid flow of the heated fluid produced by the at least one producing wellbore.

13 . The method of claim 11 , wherein the fracturing the subterranean formation in the plurality of locations proximate to the plurality of sleeves further comprises:

injecting a first amount of fracturing fluid through a first sleeve of the plurality of sleeves, wherein the first sleeve is at a first location, wherein the first location is a first distance from a toe of the injection wellbore;

engaging a second sleeve of the plurality of sleeves, wherein the second sleeve is at a second location, wherein the second location is a second distance from the toe of the injection wellbore, wherein the second distance is greater than the first distance, and wherein engaging the second sleeve isolates the first sleeve within the injection wellbore;

injecting a second amount of fracturing fluid at the second location that is the second distance from the toe of the injection wellbore; and

producing the first amount of fracturing fluid via the at least one producing wellbore to reduce pressure in the subterranean formation while the second amount of fracturing fluid is being injected at the second location.

14 . The method of claim 1 , further comprising:

positioning an external casing packer in association with a sleeve of the plurality of sleeves for isolation of the sleeve within the injection wellbore.

15 . A method of harvesting a fluid from a subterranean formation, comprising:

positioning a plurality of sleeves in an injection wellbore that extends into the subterranean formation, the plurality of sleeves each being spaced apart within the injection wellbore and threadably connected to a casing string, each sleeve of the plurality of sleeves being selectively actuatable at least between a first position and a second position, wherein a sleeve of the plurality of sleeves is annularly isolated by an external casing packer within the injection wellbore;

fracturing the subterranean formation in a plurality of locations proximate to the plurality of sleeves to enhance a plurality of fluid pathways between the injection wellbore and at least one producing wellbore that extends into the subterranean formation, wherein each location of the plurality of locations corresponds to a respective sleeve of the plurality of sleeves, wherein when the respective sleeve is in a respective one of the first position and the second position a fluid pathway of the plurality of fluid pathways extends from the respective sleeve to the at least one producing wellbore;

injecting a first fluid down the injection wellbore such that the first fluid flows into a first respective fluid pathway of the plurality of fluid pathways; and

producing a second fluid from one or more of the injection wellbore and the at least one producing wellbore, wherein fluid within a second respective fluid pathway of the plurality of fluid pathways is produced as the second fluid via in-situ stresses within the subterranean formation while the first fluid flows into the first respective fluid pathway.

16 . The method of claim 15 , wherein one or more of the injection wellbore and the at least one producing wellbore has a horizontal section for use during enhanced oil recovery or gas recovery, and wherein the second fluid is a mixture of the first fluid and either oil or gas.

Assignments (1)

Continuity (4)

References Cited (245)