Leak detection for electric submersible pump systems

1. A method of determining a presence of a leak in a wall of a production tubing string positioned within a well drilled into a subterranean formation, wherein an electrical submersible pump is positioned at a downhole end of the production tubing string and wherein the electric submersible pump is configured to pump fluids from the subterranean zone in an uphole direction through the production tubing string, the method comprising:

(a) determining, based on measurements from a pressure sensor positioned at a downhole location at a discharge end of the electrical submersible pump, that a discharge pressure of fluid flowing from the electrical submersible pump in the uphole direction through the production tubing string has decreased over a specified time period;

(b) determining, based on measurements from a pressure sensor positioned at a surface location within a wellhead of the well, that a pressure within the production tubing string at the surface has decreased over the specified time period;

(c) determining, based on measurements from a flow-rate sensor positioned at an uphole end of the production tubing string, that a flow rate of fluids from the uphole end of the production tubing string has decreased relative to a calculated expected flow rate of fluids through the production tubing string at the discharge end of the electrical submersible pump over the specified time period;

(d) initiating, in response to (a), (b), and (c), a pressure integrity test of the production tubing string; and

(e) determining, based on the pressure integrity test, the presence of the leak.

2. The method of claim 1 , further comprising determining, based on measurements from a pressure sensor positioned at a downhole location at an intake of the electrical submersible pump, that an intake pressure of fluid flowing into the electrical submersible pump has increased over the specified time period, and wherein the initiating of the pressure integrity test is further in response to the determining that the intake pressure has increased over the specified time period.

3. The method of claim 1 , further comprising determining, based on a measurement from a pressure sensor positioned within a tubing-casing annulus of the well, that a tubing-casing annulus pressure has not increased in response an initiation of operation of the electrical submersible pump, and wherein the initiating of the pressure integrity test is further in response to the determining that the tubing-casing annulus pressure has not increased in response to the initiation of the operation.

4. The method of claim 3 , wherein the well comprises a packer assembly positioned on the production tubing string above the electrical submersible pump, the packer assembly configured to prevent a flow of fluids within the tubing-casing annulus, and wherein the pressure sensor positioned within the tubing-casing annulus is uphole of the packer assembly.

5. The method of claim 4 , wherein the leak is downhole of the packer assembly.

6. The method of claim 1 , wherein the calculated expected flow rate of fluids through the production tubing string at the discharge end of the electrical submersible pump is based on an intake pressure of fluid flowing into the electrical submersible pump has increased over the specified time period.

7. The method of claim 1 , wherein the determining of the presence of the leak is a first instance of a leak detection sequence, and wherein the method further comprises a second instance of a leak detection sequence, the second instance of the leak detection sequence comprising:

determining, based on a first measurement from a pressure sensor positioned within a tubing-casing annulus of the well, that a tubing-casing annulus pressure has increased in response an initiation of operation of the electrical submersible pump;

initiating a shut-down of the electrical submersible pump;

closing a subsurface safety valve positioned on the production tubing string uphole of the electrical submersible pump;

determining, while bleeding off pressure from within the production tubing string and based on a second measurement from the pressure sensor positioned within the tubing-casing annulus, that the tubing-casing annulus pressure has decreased in response to the bleeding off of the pressure; and

determining, based on the decrease in the tubing-casing pressure in response to the bleeding off of the pressure, the presence of the leak.

8. The method of claim 7 , wherein the well comprises a packer assembly positioned on the production tubing string above the electrical submersible pump, the packer assembly configured to prevent a flow of fluids within the tubing-casing annulus, and wherein the pressure sensor positioned within the tubing-casing annulus is uphole of the packer assembly.

9. The method of claim 8 , wherein the leak is uphole of the packer assembly.

10. A computer-implemented method, comprising:

(a) determining, by a computer system and based on measurements from a pressure sensor positioned at a downhole location at a discharge end of the electrical submersible pump, that a discharge pressure of fluid flowing from the electrical submersible pump in an uphole direction through the production tubing string has decreased over a specified time period;

(b) determining, by the computer system and based on measurements from a pressure sensor positioned at a surface location within a wellhead of the well, that a pressure within the production tubing string at the surface has decreased over the specified time period;

(c) determining, by the computer system and based on measurements from a flow-rate sensor positioned at an uphole end of the production tubing string, that a flow rate of fluids from the uphole end of the production tubing string has decreased relative to a calculated expected flow rate of fluids through the production tubing string at the discharge end of the electrical submersible pump over the specified time period;

(d) initiating, in response to (a), (b), and (c), a pressure integrity test of the production tubing string; and

(e) determining, based on the pressure integrity test, the presence of the leak.

11. The computer-implemented method of claim 10 , further comprising determining, by the computer system and based on measurements from a pressure sensor positioned at a downhole location at an intake of the electrical submersible pump, that an intake pressure of fluid flowing into the electrical submersible pump has increased over the specified time period, and wherein the initiating of the pressure integrity test is further in response to the determining that the intake pressure has increased over the specified time period.

12. The computer-implemented method of claim 10 , further comprising determining, by the computer system and based on a measurement from a pressure sensor positioned within a tubing-casing annulus of the well, that a tubing-casing annulus pressure has not increased in response an initiation of operation of the electrical submersible pump, and wherein the initiating of the pressure integrity test is further in response to the determining that the tubing-casing annulus pressure has not increased in response to the initiation of the operation.

13. The computer-implemented method of claim 12 , wherein the well comprises a packer assembly positioned on the production tubing string above the electrical submersible pump, the packer assembly configured to prevent a flow of fluids within the tubing-casing annulus, and wherein the pressure sensor positioned within the tubing-casing annulus is uphole of the packer assembly.

14. The computer-implemented method of claim 13 , wherein the leak is downhole of the packer assembly.

15. The computer-implemented method of claim 10 , wherein the calculated expected flow rate of fluids through the production tubing string at the discharge end of the electrical submersible pump is based on an intake pressure of fluid flowing into the electrical submersible pump has increased over the specified time period.

16. The computer-implemented method of claim 10 , wherein the determining of the presence of the leak is a first instance of a leak detection sequence, and wherein the method further comprises a second instance of a leak detection sequence, the second instance of the leak detection sequence comprising:

determining, by the computer system and based on a first measurement from a pressure sensor positioned within a tubing-casing annulus of the well, that a tubing-casing annulus pressure has increased in response an initiation of operation of the electrical submersible pump;

initiating a shut-down of the electrical submersible pump;

closing a subsurface safety valve positioned on the production tubing string uphole of the electrical submersible pump;

determining, by the computer system and while bleeding off pressure from within the production tubing string and based on a second measurement from the pressure sensor positioned within the tubing-casing annulus, that the tubing-casing annulus pressure has decreased in response to the bleeding off of the pressure; and

determining, based on the decrease in the tubing-casing pressure in response to the bleeding off of the pressure, the presence of the leak.

17. The computer-implemented method of claim 16 , wherein the well comprises a packer assembly positioned on the production tubing string above the electrical submersible pump, the packer assembly configured to prevent a flow of fluids within the tubing-casing annulus, and wherein the pressure sensor positioned within the tubing-casing annulus is uphole of the packer assembly.

18. The computer-implemented method of claim 17 , wherein the leak is uphole of the packer assembly.