Producing fluid from a well using distributed acoustic sensing and an electrical submersible pump

Patent metadata

Field	Value
Publication number	US-12378856-B1
Application number	US-202418627074-A
Country	US
Kind code	B1
Filing date	Apr 4, 2024
Priority date	Apr 4, 2024
Publication date	Aug 5, 2025
Grant date	Aug 5, 2025

Abstract

In some embodiments, a system for producing fluid from a well can include an electrical submersible pump (ESP) disposed in a wellbore of the well and configured to pump the fluid. The system may further include a distributed acoustic sensing (DAS) system, for example having an interrogator unit and a fiber optic cable extending downhole in the wellbore. An end of the fiber optic cable can be disposed downhole relative to the ESP. In embodiments, the system may further include a controller configured to receive data from the DAS system, process the data to detect a slug, determine a parameter of the detected slug, and alter operation of the ESP in response to determining that the parameter exceeds a threshold.

First claim

What is claimed is:

1. A system for producing a fluid from a well, comprising:
an electrical submersible pump (ESP) disposed in a wellbore of the well and configured to pump the fluid;
a distributed acoustic sensing (DAS) system comprising an interrogator unit, and a fiber optic cable extending from a surface of the well into the wellbore, wherein a distal end of the fiber optic cable is disposed downhole relative to the ESP; and
a controller configured to:
receive data from the DAS system;
evaluate the data to detect a slug;
determine a parameter of the detected slug;
compare the parameter to a threshold; and
alter operation of the ESP, in response to the parameter exceeding the threshold,

wherein the slug is detected based on a tension in the fiber optic cable.

2. The system of claim 1 , wherein the interrogator unit comprises a light source configured to emit coherent light into the fiber optic cable, a receiver configured to receive backscattered light from the fiber optic cable, and a processor configured to generate the data based on the backscattered light and send the data to the controller.

3. The system of claim 1 , wherein the slug is further detected based on a measured depth range of the slug.

4. The system of claim 1 , wherein the parameter comprises a depth range of the slug, the tension in the fiber optic cable, a magnitude of an acoustic signal received by the fiber optic cable, an estimated length of the slug, an estimated volume of the slug, or an estimated mass of the slug.

5. The system of claim 1 , wherein the parameter comprises a severity rating based on at least one of a position of the slug, a velocity of the slug, a length of the slug, a volume of the slug, and a mass of the slug.

6. The system of claim 1 , wherein the parameter comprises a mass of the slug, and the mass of the slug is estimated based on a measured depth range of the slug, the tension in the fiber optic cable, a magnitude of acoustic signal received by the fiber optic cable, or combinations thereof.

7. The system of claim 1 , wherein the slug is a gas slug or a sand slug in the fluid.

8. The system of claim 1 , wherein the alteration of the operation of the ESP comprises stopping the ESP or bringing the ESP to an idle state.

9. The system of claim 1 , wherein the controller is further configured to alter the operation of the ESP by speeding up the ESP, in response to detecting that the parameter exceeds the threshold and the parameter is below another threshold.

10. The system of claim 1 , wherein the distal end of the fiber optic cable is disposed a distance downhole of the ESP, and wherein the distance is an effective distance to provide advanced warning of the slug.

11. The system of claim 1 , wherein the controller is further configured to alter operation of the ESP at a time based on an estimated position of the slug and an estimated velocity of the slug.

12. The system of claim 11 , wherein the time is sufficiently advanced for alteration of the operation of the ESP to occur prior to arrival of the slug at the ESP.

13. A method of installing a system for producing fluid from a well, comprising:
installing a distributed acoustic sensing (DAS) system, wherein the installing of the DAS system comprises:
deploying a fiber optic cable into a wellbore of the well; and
attaching an interrogator unit to a first end of the fiber optic cable;

placing an electrical submersible pump (ESP) into the wellbore, wherein a second end of the fiber optic cable is disposed downhole with respect to the ESP; and
placing a controller into communication with the DAS system, wherein the controller is configured to:
receive data from the DAS system;
evaluate the data to detect a slug;
determine a parameter of the detected slug;
compare the parameter to a threshold; and
alter operation of the ESP, in response to the parameter exceeding the threshold,

wherein the slug is detected based on a tension in the fiber optic cable.

14. The method of claim 13 , wherein the parameter comprises a depth range of the slug, the tension in the fiber optic cable, a magnitude of an acoustic signal received by the fiber optic cable, an estimated length of the slug, an estimated volume of the slug, or an estimated mass of the slug.

15. The method of claim 13 , wherein the parameter comprises a severity rating based on at least one of a position of the slug, a velocity of the slug, a length of the slug, a volume of the slug, and a mass of the slug.

16. The method of claim 13 , wherein the parameter comprises a mass of the slug, and the mass of the slug is estimated based on a measured depth range of the slug, the tension in the fiber optic cable, and a magnitude of acoustic signal received by the fiber optic cable or combinations thereof.

17. A method of producing fluid from a well, comprising:
pumping the fluid by an electrical submersible pump (ESP), wherein the ESP is disposed in a wellbore of the well;
gathering data by a distributed acoustic sensing (DAS) system, wherein a fiber optic cable of the DAS system extends from a surface of the well into the wellbore, and a distal end of the fiber optic cable is disposed downhole relative to the ESP;
evaluating the data to detect a slug;
determining a parameter of the detected slug;
comparing the parameter to a threshold; and
altering operation of the ESP, in response to the parameter exceeding the threshold,
wherein the slug is detected based on a tension in the fiber optic cable.

18. The method of claim 17 , wherein the parameter comprises a depth range of the slug, a magnitude of an acoustic signal received by the fiber optic cable, an estimated length of the slug, an estimated volume of the slug, or an estimated mass of the slug.

19. The method of claim 17 , wherein the altering of the operation of the ESP comprises stopping the ESP or bringing the ESP to an idle state.

20. The method of claim 17 , wherein the altering of the operation of the ESP comprises speeding up the ESP, in response to the parameter exceeding the threshold and the parameter being below another threshold.

Assignees

• Halliburton Energy Services Inc

Inventors

• Bridges Jeffrey
• Schaeffer Benjamin

Classifications

• E21B43/128 Primary

  Adaptation of pump systems with down-hole electric drives · CPC title

• E21B47/14 Primary

  using acoustic waves · CPC title