Pipeline monitoring systems

• US 6,644,848 B1
• Filed: 02/23/2001
• Issued: 11/11/2003
• Est. Priority Date: 06/11/1998
• Status: Expired due to Term

• Current Assignee: ABB Offshore Systems Limited (General Electric Company), Vetco Gray Controls Inc
• Original Assignee: ABB Offshore Systems Limited (General Electric Company)
• Inventors: Milanovic, Raiko, Clayton, Hugh R
• Primary Examiner(s): Gutierrez, Diego
• Assistant Examiner(s): VERBITSKY, GAIL KAPLAN
• Application Number:
  US09/701,987
• Time in Patent Office: 991 Days
• Field of Search: 374/4-6, 374/7, 374/136, 374/140, 374/143, 374/130-131, 374/110-112, 374/147-148, 374/208, 250/227.14, 250/227.11, 73/616.2
• US Class Current: 374/7
• CPC Class Codes: E21B 17/01 Risers
• CPC Class Codes: E21B 43/01 specially adapted for obtaining from underwater installations
• CPC Class Codes: F17D 3/00 Arrangements for supervising or controlling working operations
• CPC Class Codes: G01B 21/085 using thermal means
• CPC Class Codes: G01B 7/06 for measuring thickness measuring during the manufacture of coatings C23C14/54

Abstract

An oil pipeline, which connects a Christmas tree at its lower end to an oil rig at its upper end, is fitted with a stainless steel tube sheathed telecommunications grade optical fiber, forming part of a distributed temperature measurement device, such as to be in thermal contact with the oil flowing along the pipeline. Also fitted to respective ones of three discrete positions on the pipeline are ultrasonic deposit thickness measurement devices, the one nearest of which to the Christmas tree is a few hundred meters downstream from a position where preliminary studies of the pipeline system have indicated that deposits are likely to form during oil production. A computer, located on the oil rig, is connected to be able to provide control over and to receive measurement signals from the temperature measurement devices and the deposit thickness measurement devices. A model of at least deposit deposition stored in the computer is revised in response to these signals. The model includes an approximation of the temperature, the pressure and the viscosity and flow patterns of the oil along the length of the pipeline and, from these parameters, an estimation of the nature and quantity or rate of deposit deposition along the length of the pipeline.

Claims

1. A system for monitoring a pipeline, comprising:

a distributed temperature measurement means including at least one optical fibre located within the pipeline for generating temperature measurement signals, said at least one optical fiber being located adjacent an outside wall of a pipe forming part of the pipeline, and being located between the pipe and a corrosion preventing layer; and

a processing device for receiving the temperature measurement signals, and for deriving from the temperature measurement signals an estimation of deposit deposition at at least one position along the pipeline.

2. The system of claim 1, in which the processing device contains a model of at least deposit deposition on inner walls of the pipeline.

3. The system of claim 2, in which the model relates to deposit type and to deposit thickness.

4. The system of claim 1, in which the at least one optical fibre is sheathed in a stainless steel tube.

5. The system of claim 1, in Which the temperature measurement means further includes means for detecting characteristics of a laser light pulse back scattered by the at least one optical fibre, and means for providing the temperature measurement signals from the detecting means.

6. The system of claim 1, and further comprising a pressure measurement means associated with the pipeline for generating pressure measurement signals;

and in which the processing device is also operative for receiving and deriving an estimation of deposit deposition from the pressure measurement signals to determine fluid pressure at at least one location within the pipeline.

7. A system for monitoring a pipeline, comprising:

a distributed temperature measurement means including at least one optical fiber associated with the pipeline for generating temperature measurement signals;

a processing device for receiving the temperature measurement signals, and for deriving from the temperature measurement signals an estimation of deposit deposition at at least one position along the pipeline; and

a thickness measurement means associated with the pipeline for generating thickness measurement signals; and

in which the processing device is also operative for receiving and deriving an estimation of deposit deposition from the thickness measurement signals, said thickness measurement means including at least one measurement transducer located at a discrete position along the pipeline.

8. The system of claim 7, in which the at least one measurement transducer is associated with a measurement device, and the thickness measurement means includes at least two of said measurement devices.

9. The system of claim 8, in which the thickness measurement means comprises between two and ten of said thickness measurement devices located at discrete positions along the pipeline.

10. The system of claim 9, in which the thickness measurement means comprises between three and five of said thickness measurement devices.

11. The system of claim 7, in which the at least one measurement transducer is located at a position along the pipeline near which deposits are expected to form during use.

12. The system of claim 11, in which the at least one measurement transducer is an ultrasonic transducer arranged to transmit ultrasonic pulses into the pipeline.

13. The system of claim 12, in which the thickness measurement means is operative for detecting a distance between a boundary between the pipeline and a deposit, and a boundary between the deposit and a hydrocarbon flowing along the pipeline at said discrete position.

14. The system of claim 13, in which the thickness measurement means is operative for detecting a distance between the boundary of the pipeline and the deposit, and a boundary between two different types of deposit.

15. The system of claim 13, in which the processing device contains a model of at least deposit deposition on inner walls of the pipeline, and in which the model relates to deposit type and to deposit thickness, and in which a determined fraction of an acoustic signal reflected by a deposit is used to determine the deposit type.

16. Apparatus for obtaining an indication of a nature of deposits along a pipeline, comprising:

means for measuring a thickness measurement of the deposits at at least one discrete point along the pipeline;

means for measuring a temperature variation measurement along a length of the pipeline; and

means for using the two measurements to estimate a thickness of the deposits at different positions along the pipeline.