Systems and methods for estimating and controlling liquid level using periodic shut-ins

Patent metadata

Field	Value
Publication number	US-11261725-B2
Application number	US-201816165280-A
Country	US
Kind code	B2
Filing date	Oct 19, 2018
Priority date	Oct 24, 2017
Publication date	Mar 1, 2022
Grant date	Mar 1, 2022

Abstract

Methods and systems for determining a liquid level in a formation between a horizontal segment of an injection wellbore and a horizontal segment of a production wellbore are disclosed. Under shut-in conditions, local temperatures and pressures are determined for each of a plurality of inflow zones along the production wellbore segment. Local profile values are determined based on local shut-in subcool values and local shut-in liquid levels. After flow has resumed, a local liquid level is determined based on the local operating subcool value and the local profile value for that inflow zone. The local profile values may be updated during subsequent shut-ins.

First claim

The invention claimed is:

1. A method for determining a liquid level in a formation between a horizontal segment of an injection wellbore and a horizontal segment of a production wellbore, the method comprising:
shutting-in the production wellbore;
shutting-in the injection wellbore;
measuring, using at least one first temperature sensor positioned in the production wellbore segment, a local shut-in temperature for each of a plurality of inflow zones between a heel and a toe of the production wellbore segment;
measuring, using at least one first pressure sensor positioned in the production wellbore segment, a local shut-in pressure for each of the plurality of inflow zones;
determining, for each of the plurality of inflow zones:
a local shut-in liquid level, based on the measured shut-in pressure at that inflow zone and a shut-in pressure for an injection zone horizontally aligned with that inflow zone;
a local shut-in subcool value, based on the measured shut-in temperature at that inflow zone; and
a local profile value, based on the local shut-in subcool value for that inflow zone and the local shut-in liquid level for that inflow zone, the local profile value being a relationship between a change of the local shut-in subcool value and a change of the local shut-in liquid level;

resuming flow in the production wellbore;
resuming flow in the injection wellbore;
after resuming flow in the production and injection wellbores, for at least one of the plurality of inflow zones:
measuring, using the at least one first temperature sensor positioned in the production wellbore, a local operating temperature for that inflow zone;
determining a local operating subcool value, based on the measured operating temperature at that inflow zone;
determining a local operating liquid level, based on the local operating subcool value for that inflow zone and the local profile value for that inflow zone.

2. The method of claim 1 , wherein a local operating liquid level is determined for each of the plurality of inflow zones.

3. The method of claim 1 , wherein the determined local shut-in subcool value is based on a local saturation temperature of an injection fluid at the measured shut-in pressure at that inflow zone and the measured shut-in temperature at that inflow zone.

4. The method of claim 1 , further comprising, after resuming flow in the production and injection wellbores, measuring, using the at least one first pressure sensor, a local operating pressure for that inflow zone, and wherein the determined local operating subcool value is based on a local saturation temperature of the injection fluid at the measured operating pressure at that inflow zone and the measured operating temperature at that inflow zone.

5. The method of claim 1 , wherein the determined local operating liquid level is based on the local shut-in liquid level for that inflow zone, a difference between the local operating subcool value for that inflow zone and the local shut-in subcool value for that inflow zone, and the local profile value for that inflow zone.

6. The method of claim 1 , wherein the local shut-in temperature for each of the plurality of injection zones is obtained using at least one second temperature sensor positioned in the injection wellbore.

7. The method of claim 1 , wherein the local shut-in pressure for each of the plurality of injection zones is obtained using at least one second pressure sensor positioned in the injection wellbore.

8. The method of claim 1 , further comprising:
after determining the local operating liquid level for the at least one of the plurality of inflow zones:
comparing the determined local operating liquid level for the at least one of the plurality of inflow zones to a target liquid level;
in response to the determined local operating liquid level for the at least one of the plurality of inflow zones being greater than the target liquid level, performing at least one of:
increasing a pump rate of an artificial lift device to increase the total flowrate for fluids exiting the production wellbore segment;
increasing an open area of at least one of the plurality of inflow zones; and
unblocking the open area of at least one of the plurality of inflow zones; and

in response to the target liquid level being greater than the determined local operating liquid level for the at least one of the plurality of production zones, performing at least one of:
decreasing the pump rate of the artificial lift device to decrease the total flowrate for fluids exiting the production wellbore segment;
decreasing the open area of at least one of the plurality of inflow zones; and
blocking the open area of at least one of the plurality of inflow zones.

9. The method of claim 8 , wherein, in response to the determined local operating liquid level for at least one of the plurality of inflow zones being greater than the target liquid level, the method further comprises increasing an injection rate of a fluid injector to increase a total flow rate of fluids into the injector wellbore, in order to maintain pressure in a steam chamber.

10. The method of claim 8 , wherein, in response to the determined local operating liquid level for at least one of the plurality of inflow zones being greater than the target liquid level, the method further comprises decreasing an injection rate of a fluid injector to decrease a total flow rate of fluids into the injector wellbore, in order to decrease a bitumen drainage rate in a steam chamber.

11. The method of claim 8 , wherein, in response to the target liquid level being greater than the determined local operating liquid level for at least one of the plurality of inflow zones, the method further comprises decreasing an injection rate of a fluid injector to decrease a total flow rate of fluids into the injector wellbore, in order to maintain pressure in a steam chamber.

12. The method of claim 8 , wherein, in response to the target liquid level being greater than the determined local operating liquid level for at least one of the plurality of inflow zones, the method further comprises increasing an injection rate of a fluid injector to increase a total flow rate of fluids into the injector wellbore, in order to increase a bitumen drainage rate in a steam chamber.

13. The method of claim 1 , further comprising, after determining the local operating liquid level for the at least one of the plurality of inflow zones:
shutting-in the production and injection wellbores a second time;
determining updated local profile values for each of the plurality of inflow zones;
resuming flow in the production and injection wellbores a second time;
after resuming flow in the production and injection wellbores the second time, for at least one of the plurality of inflow zones:
determining an updated local operating liquid level, based on an updated local shut-in liquid level for that inflow zone, a difference between an updated local operating subcool value for that inflow zone and an updated local shut-in subcool value for that inflow zone, and the updated local profile value for that inflow zone.

14. The method of claim 1 , further comprising:
after determining the local profile values during a first shut-in period:
determining updated profile values during a second shut-in period;
determining, for at least one of the plurality of inflow zones, a profile adjustment factor based on the local profile value for that inflow zone, the updated local profile value for that inflow zone, and a duration between the first and second shut-in periods; and

after resuming flow in the production and injection we

Assignees

• Gupta Robin
• Adair Neal L
• Doraiswamy Sriram
• Long Ted A
• Exxonmobil Upstream Res Co

Inventors

• Gupta Robin
• Adair Neal L
• Doraiswamy Sriram
• Long Ted A

Classifications

• E21B43/2406 Primary

  Steam assisted gravity drainage [SAGD] · CPC title

• E21B47/06

  Measuring temperature or pressure · CPC title

• E21B47/107

  using acoustic means · CPC title

• G01V9/02

  Determining existence or flow of underground water · CPC title

• E21B47/003

  Determining well or borehole volumes · CPC title