Pipeline breach location detection systems and methods

1. A system comprising:

an inner pipe segment disposed within an outer bore, wherein the inner pipe segment comprises tubing that defines a pipe bore through the inner pipe segment and a fluid conduit within a tubing annulus of the inner pipe segment; and

a testing apparatus, wherein the testing apparatus comprises:

a test fluid source fluidly connected to the fluid conduit defined within the tubing annulus of the inner pipe segment, wherein the test fluid source is configured to inject test fluid into the tubing annulus of the inner pipe segment; and

a plurality of sensors disposed along the outer bore, wherein the plurality of sensors is configured to determine sensor data indicative of one or more downstream parameters that result due to injection of the test fluid into the tubing annulus of the inner pipe segment to enable a potential location of a breach in the tubing of the inner pipe segment to be determined based at least in part on the one or more downstream parameters that result due to injection of the test fluid into the tubing annulus of the inner pipe segment.

2. The system of claim 1 , comprising an outer pipe segment, wherein the outer bore in which the inner pipe segment is disposed is another pipe bore of the outer pipe segment.

3. The system of claim 1 , wherein the testing apparatus comprises a control sub-system communicatively coupled to the plurality of sensors, wherein:

the plurality of sensors comprise a plurality of fluid composition sensors that are disposed along the outer bore and each configured to determine sensor data indicative of amount of the test fluid at a corresponding location in the outer bore; and

the control sub-system is configured to determine that the breach in the tubing of the inner pipe segment is potentially closest in proximity to a fluid composition sensor in the plurality of fluid composition sensors that determined sensor data indicative of a largest amount of the test fluid.

4. The system of claim 3 , wherein the control sub-system is configured to:

determine a trend of the amount of the test fluid over a length within the outer bore by interpolating the sensor data determined by the plurality of fluid composition sensors; and

determine the potential location of the breach in the tubing of the inner pipe segment based at least in part on a maximum in the trend of the amount of the test fluid.

5. The system of claim 3 , wherein:

a first fluid composition sensor in the plurality of fluid composition sensors is configured to time stamp first sensor data to indicate a first time when a first amount of the test fluid at the first fluid composition sensor exceeds a test fluid amount threshold;

a second fluid composition sensor in the plurality of fluid composition sensors is configured to time stamp second sensor data to indicate a second time when a second amount of the test fluid at the second fluid composition sensor exceeds the test fluid amount threshold; and

the control sub-system is configured to:

determine a first travel distance of the test fluid to the first fluid composition sensor based at least in part on the first time that is time stamped in the first sensor data determined by the first fluid composition sensor and an expected propagation rate of the test fluid within the system;

determine a second travel distance of the test fluid to the second fluid composition sensor based at least in part on the second time that is time stamped in the second sensor data determined by the second fluid composition sensor and the expected propagation rate of the test fluid within the system; and

determine the potential location of the breach in the tubing of the inner pipe segment at least in part by cross-correlating the first travel distance of the test fluid to the first fluid composition sensor and the second travel distance of the test fluid to the second fluid composition sensor based at least in part on a first location of the first fluid composition sensor in the outer bore and a second location of the second fluid composition sensor in the outer bore.

6. The system of claim 3 , wherein:

the test fluid injected into the tubing annulus of the inner pipe segment comprises radioactive tracer fluid; and

each fluid composition sensor in the plurality of fluid composition sensors is configured to determine sensor data indicative of the amount of the test fluid at a corresponding location in the outer bore based at least in part on one or more radioactive signals received from environmental conditions within the outer bore.

7. The system of claim 1 , wherein the testing apparatus comprises a control sub-system communicatively coupled to the plurality of sensors, wherein:

the plurality of sensors in the testing apparatus comprises a plurality of temperature sensors that are disposed along the outer bore and each configured to determine sensor data indicative of actual fluid temperature at a corresponding location in the outer bore; and

the control sub-system is configured to determine that the breach in the tubing of the inner pipe segment is potentially closest in proximity to a temperature sensor in the plurality of temperature sensors that determined sensor data indicative of a smallest difference between actual fluid temperature and an expected test fluid temperature associated with the temperature sensor.

8. The system of claim 1 , wherein the testing apparatus comprises a control sub-system communicatively coupled to the plurality of sensors, wherein:

the plurality of sensors comprises a plurality of audio sensors that are disposed along the outer bore and each configured to determine sensor data indicative of noise level at a corresponding location in the outer bore; and

the control sub-system is configured to determine that the breach in the tubing of the inner pipe segment is potentially closest in proximity to an audio sensor in the plurality of audio sensors that determined sensor data indicative of a loudest noise level.

9. The system of claim 8 , wherein the control sub-system is configured to:

determine a trend of the noise level over a length within the outer bore at least in part by interpolating the sensor data determined by the plurality of audio sensors; and

determine the potential location of the breach in the tubing of the inner pipe segment based at least in part on a maximum in the trend of the noise level.

10. The system of claim 8 , wherein:

a first audio sensor in the plurality of audio sensors is configured to time stamp first sensor data to indicate a first time when a first pipeline noise level at the first audio sensor exceeds a pipeline noise level threshold;

a second audio sensor in the plurality of audio sensors is configured to time stamp second sensor data to indicate a second time when a second pipeline noise level at the second audio sensor exceeds the pipeline noise level threshold; and

the control sub-system is configured to determine the potential location of the breach in the tubing of the inner pipe segment based at least in part on the first time that is time stamped in the first sensor data determined by the first audio sensor, a first location of the first audio sensor in the outer bore, the second time that is time stamped in the second sensor data determined by the second audio sensor, a second location of the second audio sensor in the outer bore, and an expected propagation rate of sound within the outer bore.

11. The system of claim 1 , comprising:

a first sensor opening formed through a bore surface that defines the outer bore; and

a second sensor opening formed through the bore surface that defines the outer bore, wherein a sensor in the plurality of sensors in the testing apparatus is:

disposed within the first sensor opening and configured to determine first sensor data indicative of a first downstream parameter that results due to injection of the test fluid into the tubing annulus of the inner pipe segment during a first time period; and

disposed within the second sensor opening and configured to determine second sensor data indicative of a second downstream parameter that results due to injection of the test fluid into the tubing annulus of the inner pipe segment during a second time period after the first time period.

12. The system of claim 11 , wherein the testing apparatus comprises a plug:

disposed within the second sensor opening to seal the second sensor opening during the first time period; and

disposed within the first sensor opening to seal the first sensor opening during the second time period after the first time period.

13. The system of claim 1 , wherein:

the plurality of sensors is configured to:

determine first sensor data indicative of first one or more downstream parameters that result along a length of the outer bore due to injection of the test fluid into the tubing annulus of the inner pipe segment a first time; and

determine second sensor data indicative of second one or more downstream parameters that result along a section of the outer bore due to injection of the test fluid into the tubing annulus of the inner pipe segment a second time after the first time; and

a control sub-system is configured to:

determine that the breach in the tubing of the inner pipe segment is potentially located in the section of the outer bore based on the first one or more downstream parameters that result due to injection of the test fluid into the tubing annulus of the inner pipe segment the first time; and

determine the potential location of the breach within the section of the outer bore based on the second one or more downstream parameters that result due to injection of the test fluid into the tubing annulus of the inner pipe segment the second time.

14. A method of operating a testing apparatus deployed in a pipeline system, comprising:

instructing, using a control sub-system of the testing apparatus, a test fluid source of the testing apparatus to inject test fluid into free space defined within a tubing annulus of an inner pipe segment in the pipeline system, wherein the inner pipe segment is disposed within an outer bore;

determining, using the control sub-system, one or more downstream parameters that result due to injection of the test fluid into the tubing annulus of the inner pipe segment based at least in part on sensor data determined by a plurality of sensors of the testing apparatus that is disposed along the outer bore;

determining, using the control sub-system, whether a breach is potentially present in the inner pipe segment based at least in part on the one or more downstream parameters that result due to injection of the test fluid into the tubing annulus of the inner pipe segment; and

in response to determining that a breach is potentially present in the inner pipe segment, determining, using the control sub-system, a potential location of the breach based at least in part on the one or more downstream parameters that result due to injection of the test fluid into the tubing annulus of the inner pipe segment.

15. The method of claim 14 , wherein:

determining the one or more downstream parameters comprises determining amount of the test fluid at a sensor in the plurality of sensors, determining a noise level at the sensor in the plurality of sensors, or both; and

determining whether a breach is potentially present in the inner pipe segment comprises determining that the breach is potentially present in the inner pipe segment when the amount of the test fluid at the sensor exceeds a test fluid amount threshold, when the noise level at the sensor is indicative of whooshing, or both.

16. The method of claim 14 , wherein:

determining the one or more downstream parameters comprises determining first sensor data indicative of amount of the test fluid at each of the plurality of sensors, determining second sensor data indicative of pipeline noise level at each of the plurality of sensors, or both; and

determining the potential location of the breach comprises:

determining a first trend of the amount of the test fluid over a length within the pipeline system at least in part by interpolating the first sensor data, determining a second trend of the pipeline noise level of the length within the pipeline system at least in part by interpolating the second sensor data; and

determining the potential location of the breach in the inner pipe segment based at least in part on a first maximum in the first trend of the amount of the test fluid, a second maximum in the second trend of the pipeline noise level, or both.

17. The method of claim 14 , wherein:

determining the one or more downstream parameters comprises:

determining first sensor data that is time stamped to indicate a first time when amount of the test fluid at a first sensor in the plurality of sensors exceeds a test fluid amount threshold, when pipeline noise level at the first sensor exceeds a pipeline noise level threshold, or both; and

determining second sensor data that is time stamped to indicate a second time when amount of the test fluid at a second sensor in the plurality of sensors exceeds the test fluid amount threshold, when pipeline noise level at the second sensor exceeds the pipeline noise level threshold, or both; and

determining the potential location of the breach comprises determining the potential location of the breach in the inner pipe segment based at least in part on the first time that is time stamped in the first sensor data, a first location of the first sensor in the pipeline system, the second time that is time stamped in the second sensor data, and a second location of the second sensor in the pipeline system.

18. The method of claim 14 , wherein:

instructing the test fluid source to inject the test fluid comprises:

instructing the test fluid source to inject the test fluid into the free space defined within the tubing annulus of the inner pipe segment a first time; and

instructing the test fluid source to inject the test fluid into the free space defined within the tubing annulus of the inner pipe segment a second time after the first time;

determining the one or more downstream parameters comprises:

determining a first one or more downstream parameters that result due to injection of the test fluid into the tubing annulus of the inner pipe segment the first time based at least in part on first sensor data determined by the plurality of sensors while disposed along a length of the pipeline system; and

determining a second one or more downstream parameters that result due to injection of the test fluid into the tubing annulus of the inner pipe segment the second time based at least in part on second sensor data determined by the plurality of sensors while disposed along a section in the length of the pipeline system; and

determining the potential location of the breach comprises:

determining that the breach is potentially located within the section of the pipeline system based at least in part on the first one or more downstream parameters; and

determining the potential location of the breach within the section of the pipeline system based at least in part on the second one or more downstream parameters.

19. A testing apparatus to be deployed in a pipeline system, comprising:

a test fluid source configured to be fluidly connected to free space defined within a tubing annulus of an inner pipe segment in the pipeline system to enable the test fluid source to inject test fluid into the tubing annulus of the inner pipe segment;

a plurality of sensors configured to be disposed along an outer bore in the pipeline system to enable the plurality of sensors to determine sensor data indicative of one or more downstream parameters that result due to the test fluid being injected into the tubing annulus of the inner pipe segment, wherein the inner pipe segment is disposed within the outer bore; and

a control sub-system configured to be communicatively coupled to the plurality of sensors to enable the control sub-system to:

determine one or more downstream parameter trends that result due to the test fluid being injected into the tubing annulus of the inner pipe segment based at least in the sensor data determined by the plurality of sensors;

and determine a potential location of a breach in the inner pipe segment based at least in part on a maximum in the one or more downstream parameter trends.

20. The testing apparatus of claim 19 , wherein:

the plurality of sensors comprises:

a plurality of fluid composition sensors configured to be disposed along the outer bore to enable the plurality of fluid composition sensors to determine first sensor data indicative of amount of the test fluid in the outer bore due to the test fluid being injected into the tubing annulus of the inner pipe segment;

a plurality of audio sensors configured to disposed along the outer bore to enable the plurality of audio sensors to determine second sensor data indicative of pipeline noise level in the outer bore due to the test fluid being injected into the tubing annulus of the inner pipe segment; or

both; and

the control sub-system is configured to:

determine a first trend of the amount of the test fluid along the outer bore at least in part by interpolating the first sensor data determined by the plurality of fluid composition sensors;

determine a second trend of the pipeline noise level along the outer bore at least in part by interpolating the second sensor data determined by the plurality of audio sensors; or

both.