In situ hydrocarbon recovery using distributed flow control devices for enhancing temperature conformance

Patent metadata

Field	Value
Publication number	US-9702233-B2
Application number	US-201414296971-A
Country	US
Kind code	B2
Filing date	Jun 5, 2014
Priority date	May 30, 2014
Publication date	Jul 11, 2017
Grant date	Jul 11, 2017

Abstract

Hydrocarbon recovery can involve operating flow control devices distributed along a horizontal well based on temperatures of hydrocarbon-containing fluids at a plurality of locations along the horizontal well. The temperatures of hydrocarbon-containing fluids can indicate a presence of a hotter overlying reservoir region and an adjacent colder overlying reservoir region. The operation of the distributed flow control devices can involve reducing flow of hydrocarbon-containing fluid from the hotter overlying reservoir region into the horizontal well, while providing fluid communication and pressure differential between the colder overlying reservoir region and the production well, sufficiently to cause hot fluids surrounding the colder overlying reservoir region to be drawn into and induce heating of the colder overlying reservoir region.

First claim

The invention claimed is:

1. A process for hydrocarbon recovery, comprising:
providing a Steam-Assisted Gravity Drainage (SAGD) well pair in a hydrocarbon-containing reservoir, the well pair including a generally horizontal SAGD injection well overlying a generally horizontal SAGD production well;
identifying a hotter overlying reservoir region and an adjacent colder overlying reservoir region based on measured temperatures of hydrocarbon-containing fluids at a plurality of locations along the horizontal SAGD production well obtained using a plurality of temperature sensors; and
operating flow control devices distributed along the horizontal SAGD production well based on the measured temperatures of the hydrocarbon-containing fluids, the operating comprising:
reducing flow of hydrocarbon-containing fluid from the hotter overlying reservoir region into the horizontal SAGD production well, while
providing fluid communication and pressure differential between the colder overlying reservoir region and the horizontal SAGD production well, sufficiently to cause hot fluids surrounding the colder overlying reservoir region to be drawn into and induce heating of the colder overlying reservoir region,
the step of operating the flow control devices further comprising:
reducing flow of hydrocarbon-containing fluid from the hotter overlying reservoir region when the hydrocarbon-containing fluid from the hotter overlying reservoir region reaches an upper threshold temperature;
allowing the hydrocarbon-containing fluid from the hotter overlying reservoir region to cool to a lower threshold temperature; and then
increasing flow of the hydrocarbon-containing fluid from the hotter overlying reservoir region.

2. The process according to claim 1 , wherein the hotter overlying reservoir region is located above one of a toe and a heel of the horizontal SAGD production well.

3. The process according to claim 1 , further comprising:
partitioning the horizontal SAGD production well into well segments, each well segment being associated with at least one of the flow control devices.

4. The process according to claim 3 , wherein the step of partitioning the horizontal SAGD production well into well segments comprises providing isolation devices positioned along the horizontal SAGD production well.

5. The process according to claim 3 , wherein the step of operating the flow control devices further comprises:
reducing flow of hydrocarbon-containing fluid from the hotter overlying reservoir region into at least one well segment located below the hotter overlying reservoir region, while
providing fluid communication and pressure differential between at least one well segment located below the colder overlying reservoir region and the horizontal SAGD production well.

6. The process according to claim 3 , wherein each isolation device is located between two adjacent ones of the flow control devices.

7. The process according to claim 3 , wherein the well segments comprise at least three well segments.

8. The process according to claim 3 , wherein each well segment has a length of between about 10 and about 500 meters.

9. The process according to claim 1 , wherein the plurality of temperature sensors comprises a plurality of distributed fiber-optic temperature sensors positioned along the horizontal SAGD production well.

10. The process according to claim 1 , wherein the flow control devices comprise hydraulically actuated valves.

11. The process according to claim 1 , wherein the upper threshold temperature and the lower threshold temperature are based on a targeted upper sub-cool temperature and a targeted lower sub-cool temperature, respectively.

12. The process according to claim 1 , wherein the upper threshold temperature is lower than a temperature of steam injected into the horizontal SAGD injection well.

13. The process according to claim 1 , wherein the step of providing fluid communication and pressure differential between the colder overlying reservoir region and the horizontal SAGD production well is performed at a first pressure drawdown, and wherein the step of increasing the flow of the hydrocarbon-containing fluid from the hotter overlying reservoir region is performed at a second pressure drawdown lower than the first pressure drawdown.

14. The process according to claim 1 , wherein the step of operating the flow control devices comprises operating the flow control devices located below the colder overlying reservoir region in an open position.

15. The process according to claim 1 , wherein the step of operating the flow control devices comprises impeding flow from the hotter overlying reservoir region into the horizontal SAGD production well while enabling a lower flow rate through the flow control devices.

16. A process for hydrocarbon recovery, comprising:
providing a Steam-Assisted Gravity Drainage (SAGD) well pair in a hydrocarbon-containing reservoir, the well pair including a generally horizontal SAGD injection well overlying a generally horizontal SAGD production well;
identifying a hotter overlying reservoir region and an adjacent colder overlying reservoir region based on measured temperatures of hydrocarbon-containing fluids at a plurality of locations along the horizontal SAGD production well obtained using a plurality of temperature sensors; and
operating flow control devices distributed along the horizontal SAGD production well based on the measured temperatures of the hydrocarbon-containing fluids, the operating comprising:
reducing flow of hydrocarbon-containing fluid from the hotter overlying reservoir region into the horizontal SAGD production well, while
providing fluid communication and pressure differential between the colder overlying reservoir region and the horizontal SAGD production well, sufficiently to cause hot fluids surrounding the colder overlying reservoir region to be drawn into and induce heating of the colder overlying reservoir region,

the step of operating the flow control devices further comprising at least one of:
maintaining a reduced flow of hydrocarbon-containing fluid from the hotter overlying reservoir region into the horizontal SAGD production well until a level of hydrocarbon-containing fluid in the hotter overlying reservoir region reaches an upper threshold level; and then increasing flow of the hydrocarbon-containing fluid from the hotter overlying reservoir region;
maintaining a reduced flow of hydrocarbon-containing fluid from the hotter overlying reservoir region into the horizontal SAGD production well until an average of the measured temperatures along the colder overlying reservoir region reaches an upper threshold value; and then increasing flow of the hydrocarbon-containing fluid from the hotter overlying reservoir region; and
maintaining a reduced flow of hydrocarbon-containing fluid from the hotter overlying reservoir region into the horizontal SAGD production well until a variance of the measured temperatures along the horizontal SAGD production well relative to a maximum measured temperature reaches a lower threshold variance, such that the hotter and colder overlying reservoir regions together form an overlying conformance reservoir region; and then increasing flow of the hydrocarbon-containing fluid from the former hotter overlying reservoir region.

17. The process according to claim 16 , further comprising:
partitioning the horizontal SAGD production well into well segments, each well segment being associated with at least one of the flow control devices.

18. The process according to clai

Assignees

• Suncor Energy Inc

Inventors

• Stahl Richard
• Smith Jennifer

Classifications

• E21B43/14 Primary

  Obtaining from a multiple-zone well · CPC title

• E21B43/2406

  Steam assisted gravity drainage [SAGD] · CPC title