Determining fluid leakage volume in pipelines

Patent metadata

Field	Value
Publication number	US-9897261-B2
Application number	US-201615373821-A
Country	US
Kind code	B2
Filing date	Dec 9, 2016
Priority date	Jun 27, 2011
Publication date	Feb 20, 2018
Grant date	Feb 20, 2018

Abstract

A method and an apparatus for determining leakage volume of fluid in transportation pipelines are provided. The method comprises: obtaining the negative pressure wave signals detected by at least two pressure sensors arranged on the pipeline; determining the pressure signal at the leakage location based on the negative pressure wave signals; determining the leakage rate during a leakage period based on the pressure signal at the leakage location according to a leakage model; and determining the leakage volume of the fluid in the pipeline based on the leakage rate and the leakage period. The apparatus provided corresponds to the method described above. By using the method and apparatus described above, the leakage volume of the transportation pipelines can be obtained to help understand the leakage profile of the pipelines and thus reduce losses (FIG. 1 ).

First claim

What is claimed is:

1. A computer program product comprising a non-transitory computer readable storage medium having a computer readable program stored thereon, wherein the computer readable program, when executed by a processor, causes the processor to:
obtain negative pressure wave signals detected by at least two pressure sensors arranged on the pipeline; wherein the at least two pressure sensors are arranged on the pipeline such that, for each whole straight segment of the pipeline, one or more pressure sensors of the at least two pressure sensors are arranged at least at each end of the respective whole straight segment of the pipeline;
determine a pressure signal at a leakage location based on the negative pressure wave signals;
determine a leakage rate during a leakage period based on the pressure signal at the leakage location according to a leakage model; and
determine the leakage volume of the fluid in the pipeline based on the leakage rate and the leakage period.

2. The computer program product according to claim 1 , wherein the at least two pressure sensors comprises the two pressure sensors closest to the leakage location.

3. The computer program product according to claim 1 , wherein the program instructions are further configured to cause the processor to obtain the negative pressure wave signals by processing the read negative pressure wave signals by a low pass filter.

4. The computer program product according to claim 1 , wherein the program instructions are further configured to cause the processor to determine the pressure signal at the leakage location by:
determining the leakage location based on the negative pressure wave signals; and
determining the pressure signal at the leakage location according to the obtained negative pressure wave signals and the determined leakage location.

5. The computer program product according to claim 4 , wherein determining the pressure signal at the leakage location according to the obtained negative pressure wave signals and the determined leakage location comprises: deducing the pressure signal at the leakage location by using a linear model in which the fluid pressure changes linearly along the pipeline, based on the negative pressure waves signals at the at least two pressure sensors, and the distances from the leakage location to the at least two pressure sensors.

6. The computer program product according to claim 1 , wherein the program instructions are further configured to cause the processor to determine the leakage rate during a leakage period by determining the leakage rate as being proportional to the pressure intensity at the leakage location according to a proportional leakage model.

7. The computer program product according to claim 1 , wherein the program instructions are further configured to cause the processor to determine the leakage rate during a leakage period by:
obtaining the slope information of the pressure signal at the leakage location over time;
dividing the leakage period into a plurality of time segments according to the slope information; and
determining the leakage rate in each time segment according to the leakage model.

8. The computer program product according to claim 7 , wherein determining the leakage rate in each time segment comprises selecting from a group comprising at least one of:
determining the leakage rate according to the ratio of the stable pressure intensity in each time segment to a particular pressure intensity;
estimating the leakage rate according to the stable pressure intensity in each time segment and a fluid function; and
determining the leakage rate by referring to a query table.

9. The computer program product according to claim 7 , wherein determining the leakage volume of the fluid in the pipeline based on the leakage rate comprises:
summating the leakage volumes in each time segment; and
obtaining the total leakage volume during the leakage period.

10. The computer program product according to claim 1 , wherein the program instructions are further configured to cause the processor to:
provide users with a model library comprising various leakage models and options of leakage models via an appropriate interface; and
receive the selection of leakage models made by users via the interface.

11. The computer program product according to claim 1 , the program instructions are further configured to cause the processor to receive the definition of leakage models made by users.

Assignees

• IBM

Inventors

• Albertao Felipe
• Chen Ying
• Huang Jin
• Tian Chunhua
• Wang Hao
• Xiao Jing

Classifications

• G01M3/2815

  using pressure measurements · CPC title

• F17D5/02 Primary

  Preventing, monitoring, or locating loss · CPC title

• F17D5/06 Primary

  using electric or acoustic means · CPC title

• G01F22/02

  involving measurement of pressure · CPC title

• G01F1/34

  by measuring pressure or differential pressure · CPC title