WO2006010874A1 - Systeme et procede permettant de remedier aux obstructions dans un pipe-line - Google Patents

Systeme et procede permettant de remedier aux obstructions dans un pipe-line Download PDF

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Publication number
WO2006010874A1
WO2006010874A1 PCT/GB2005/001003 GB2005001003W WO2006010874A1 WO 2006010874 A1 WO2006010874 A1 WO 2006010874A1 GB 2005001003 W GB2005001003 W GB 2005001003W WO 2006010874 A1 WO2006010874 A1 WO 2006010874A1
Authority
WO
WIPO (PCT)
Prior art keywords
fluid
pipe
tubing
space
remote location
Prior art date
Application number
PCT/GB2005/001003
Other languages
English (en)
Inventor
David B. Andersen
Michael A. Mattern
Colin Headworth
Original Assignee
Halliburton Energy Services, Inc.
Wain, Christopher, Paul
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Halliburton Energy Services, Inc., Wain, Christopher, Paul filed Critical Halliburton Energy Services, Inc.
Publication of WO2006010874A1 publication Critical patent/WO2006010874A1/fr

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
    • E21B21/12—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using drilling pipes with plural fluid passages, e.g. closed circulation systems
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B37/00—Methods or apparatus for cleaning boreholes or wells

Definitions

  • pipeline systems are used to transport unprocessed and untreated petroleum production fluids from a petroleum reservoir in the sea bed to a production facility, or the like, floating on the surface of the sea.
  • hydrates hydrates, wax and/or other types of compounds (hereinafter collectively referred to as "hydrates") will form which can cause blockage of the pipeline.
  • the fluids come from the reservoir at a relatively high temperature, they will cool down when flowing through the subsea pipeline and especially when they sit in the pipeline when the flow terminates. In either case, the fluids can cool down below the above threshold temperature causing the hydrates to form.
  • Fig. 1 is an elevational view of a subsea petroleum operation including an embodiment of the invention.
  • Fig. 2 is an enlarged sectional view of a portion of the pipe of Fig. 1.
  • Figs. 3-6 are views, similar to that of Fig. 2, but depicting alternative embodiments.
  • the reference numeral 10 refers to a pipe that forms a riser and a flow line in a subsea petroleum recovery operation.
  • the pipe 10 extends between a production facility 12 that floats on the surface of the sea S, and a tree system 14 extending just above a subsea well 16.
  • a production facility 12 that floats on the surface of the sea S
  • a tree system 14 extending just above a subsea well 16.
  • the tree system 14 is supported at the upper surface of the sea bed B and the well 16 extends into the sea bed for recovering petroleum based production fluid from a formation formed in the sea bed.
  • the tree system 14 is conventional and, as such, includes a series of valves and associated components (not shown) for controlling the flow of the production fluid in the pipe 10.
  • the production fluid flows from the well 16, through the tree system 14 and the pipe 10 and to the production facility 12 for further processing, under control of the tree system 14.
  • the production fluid from the well 16 is at a relatively high temperature, it will cool down when flowing through the pipe 10 and/or when it is confined in the pipe when the flow terminates. It will be assumed that the relatively high static head and fluid pressure in the pipe 10 causes the above threshold temperature, e.g., the temperature below which hydrates are formed, to be relatively high and that the temperature of the fluid falls below this threshold temperature therefore causing the hydrates to form in the pipe, as discussed above.
  • the above threshold temperature e.g., the temperature below which hydrates are formed
  • the normal flow of production fluid from the well 16 and into the pipe 10 is terminated by closing the proper valves in the tree system 14 (Fig. 1), and a section of coiled tubing 18 is installed in the pipe 10.
  • the lower end of the tubing 18 is inserted into the pipe and lowered from a supply reel, or the like, at the production facility 12 until the latter end reaches a predetermined depth in the pipe, which corresponds to the depth sufficient to remove the head of liquid in the pipe, as will be explained.
  • the lower end of the tubing 18 extending in the pipe 10 is open and receives production fluid under conditions to be described.
  • An annular space 20 is formed between the outer diameter of the tubing 18 and the inner diameter of the corresponding section of the pipe, and continues to the production facility 12.
  • production fluid from the well 16 accumulates in the tubing 18 and in the space 20 and creates a static head and a relatively high fluid pressure.
  • a supply of compressible, relatively low-density fluid, such as nitrogen or hydrocarbon gas, (hereinafter referred to as "gas") from the production facility 12 is then introduced into the upper end of the space 20.
  • gas compressible, relatively low-density fluid, such as nitrogen or hydrocarbon gas
  • the gas passes through the space 20 in a direction as shown by the arrows A which is in a direction towards the well 16, and is introduced at a pressure sufficient to displace the production fluid in the space.
  • the displaced production fluid is forced into the end of the tubing 18 as shown by the arrows B, before passing through the tubing in a direction towards the production facility 12 shown by the arrows C. During this movement, the original production fluid in the tubing 18 is also displaced.
  • the gas flowing down the space 20 reaches the end of the tubing 18, most of the production fluid is evacuated from the space 20 and the tubing 18 and passed to the production facility 12. The gas will then start flowing up the space 20 and the tubing 18 and carry any remaining production fluid with it.
  • the system is depressurized either via the space and/or via the tubing 18.
  • the remaining production fluids will be allowed to expand and flow naturally to the production facility by a variety of physical phenomena including the expansion of the relatively low vapor pressure production fluid and/or the vaporization of the high vapor pressure gas.
  • the tubing 18 can be removed from the pipe 10, and the normal flow of production fluid from the well 16, through the pipe 10 and to the production facility 12, can be restarted under control of the valves in the tree system 14.
  • Fig. 3 contains several components of the embodiment of Fig. 2, which are given the same reference numerals. It will be assumed that the relatively high static head and fluid pressure in the pipe 10 causes the above threshold temperature, e.g., the temperature below which hydrates are formed, to be relatively high and that the temperature of the fluid falls below this threshold temperature therefore causing the hydrates to form in the pipe, as discussed above.
  • the above threshold temperature e.g., the temperature below which hydrates are formed
  • the tubing 18 is kept void of production fluid during the above insertion of the packer 26 by maintaining a gas pressure on the tubing or by the use of a special check valve (not shown) that can be controlled by pressure variations in the tubing.
  • the gas in the tubing 18 is then vented to the production facility 12 (Fig. 1) or the above check valve is opened, causing the production fluid below the packer 26 to expand and flow upwardly in the tubing and to the production facility.
  • the static head and fluid pressure in the pipe 10 is determined according to this height of the gas/liquid interface and the pressure of the gas above the interface. With the tubing 18 and the packer 26 in place and the tubing 18 depressurized in accordance with the above, the interface is likely to be lower than the original head in the pipe 10 before the tubing 18 and the packer are introduced, and thus the final equilibrium pressure in the pipe 10 will be lower.
  • the depth to which the tubing 18 and the packer 26 are inserted can be selected to ensure that the final equilibrium pressure is low enough to lower the temperature of the fluid in the pipe to a value below the above-mentioned threshold temperature, and thus cause melting of the hydrates by the heat in the fluid and the surroundings, and the elimination of any blockage in the pipe 10.
  • the tubing 18 and the packer 26 can be removed from the pipe 10, and the normal flow of production fluid from the well 16, through the pipe 10 and to the production facility 12, can be restarted.
  • Fig. 4 contains several components of the embodiment of Fig. 3, which are given the same reference numerals.
  • a submersible electric motor 30 is connected to the lower end of the tubing 18 and is operatively connected to a submersible pump 32.
  • the relatively high static head and fluid pressure in the pipe 10 causes the above threshold temperature, e.g., the temperature below which hydrates are formed, to be relatively high and that the temperature of the fluid falls below this threshold temperature therefore causing the hydrates to form in the pipe, as discussed above.
  • the above threshold temperature e.g., the temperature below which hydrates are formed
  • the normal flow of production fluid from the well 16 and into the pipe 10 is terminated by closing the proper valves in the tree system 14, and the coiled tubing 18 is installed in the pipe 10 in the manner discussed above.
  • the motor 30 is activated to drive the pump 32 to lift the production fluid from that portion of the pipe 10 extending below the tubing 18, and pass the fluid through the tubing 18 and the pipe 10 to the production facility 12 (Fig. 1), as shown by the arrows A. Also, the pump 32 pumps the fluid from that portion of the space 20 extending below the packer 26, through the tubing 18, and to the production facility 12 (Fig. 1), as shown by the arrows B. As production fluid is pumped from the pipe 10 and the space 20 in the above manner, the packer 26 prevents the production fluid in the space 20 above the packer from flowing downwardly.
  • the static head and the fluid pressure in the pipe 10 will be quickly reduced and the temperature of the fluid is lowered to a value below the above-mentioned threshold temperature, thus causing melting of the hydrates by the heat in the fluid and the surroundings, and the elimination of any blockage in the pipe 10.
  • the tubing 18, the packer 26, the pump 30 and the motor 32 can be removed from the pipe 10, and the normal flow of production fluid from the well 16, through the pipe 10 and to the production facility 12, can be restarted.
  • the pump 30 and the motor 32 can be replaced by a hydraulic power turbine in which case separate conduits could be provided to convey the hydraulic production fluid supply, the hydraulic production fluid return and the fluid being removed from the pipe.
  • a length of flexible tubing could be installed on the suction end of the pump 30 to extend the reach of the production fluid removal capability of the system to some point significantly beyond the location of the pump.
  • the packer 26 can be eliminated and the fluid in the entire space 20 removed by the pump 32.
  • the embodiment of Fig. 5 includes components of the previous embodiments, which are given the same reference numerals.
  • the normal flow of production fluid from the well 16 and into the pipe 10 is terminated by closing the proper valves in the tree system 14 (Fig. 1), and two radially spaced, concentric coiled tubes 18a and 18b are installed in the pipe 10.
  • the lower ends of the tubes 18a and 18b are inserted into the pipe 10 and lowered from a supply reel, or the like, at the production facility 12 (Fig. 1) until the latter ends reach a predetermined depth in the pipe, which corresponds to the depth sufficient to remove the head of liquid in the pipe.
  • a space 20 extends between the outer surface of the tube 18b and the inner surface of the pipe 10.
  • a space 36 is formed between the outer surface of the tube 18a and the inner surface of the tube 18b and extends to the production facility 12.
  • a packer 26 is lowered into the space 20 to a desired depth and then set in place to seal against production fluid flow across it in a conventional manner and therefore isolate that portion of the space 20 extending above the packer from that portion extending below, as viewed in Fig. 3.
  • a supply of compressible, relatively low-density fluid, such as nitrogen or hydrocarbon gas, (hereinafter referred to as "gas") from the production facility 12 is then introduced into the upper end of the space 36.
  • gas compressible, relatively low-density fluid, such as nitrogen or hydrocarbon gas
  • the gas passes through the space 36 in a direction as shown by the arrows A which is in a direction towards the well 16, and is introduced at a pressure sufficient to displace the production fluid in the space.
  • the displaced production fluid is forced into the end of the tube 18a as shown by the arrows B, before passing through the latter tube in a direction towards the production facility 12 shown by the arrows C. During this movement, the original production fluid in the tube 18a is also displaced.
  • the gas flowing down the space 36 reaches the end of the tubes 18a, most of the production fluid is evacuated from the space 36 and the tube 18a and passed to the production facility 12. The gas will then start flowing up the space 36 and the tubes 18a and 18b and carry the production fluid with it.
  • the cross section of the flow path through the space 36, as well as the flow path defined in the interior of the tube 18a, is significantly smaller than the diameter of the pipe 10. This promotes the lifting of the production fluid up the tube 18a and the space 36 in accordance with the above.
  • the supply of the gas to the space 36 is stopped, the system is depressurized either via the space or the tubing and the remaining production fluid allowed to expand and flow naturally to the production facility 12 via the tubes 18a and 18b by a variety of physical phenomena including the expansion of the relatively low vapor pressure production fluid and/or the vaporization of the high vapor pressure gas.
  • this evacuation of the production fluid from the space 36 and the tubes 18a and 18b in the foregoing manner significantly reduces the static head and fluid pressure in the space and the tubing.
  • the reduction of the static head and fluid pressure in the pipe 10 lowers the temperature of the fluid in the pipe to a value below the above- mentioned threshold temperature, and thus causes melting of the hydrates by the heat in the fluid and the surroundings, and the elimination of any blockage in the pipe 10.
  • the tubes 18a and 18b and the packer 26 can be removed from the pipe 10, and the normal flow of production fluid from the well 16, through the pipe 10 and to the production facility 12, can be restarted.
  • Fig. 6 contains several components of the embodiment of Fig. 2, which are given the same reference numerals, and, as in the previous embodiments, it will be assumed that production fluid is present in the tubing 18 and in the space 20 between the tubing 18 and the pipe 10. It will be assumed that the relatively high static head and fluid pressure in the pipe 10 causes the above threshold temperature, e.g., the temperature below which hydrates are formed, to be relatively high and that the temperature of the fluid falls below this threshold temperature therefore causing the hydrates to form in the pipe, as discussed above.
  • the above threshold temperature e.g., the temperature below which hydrates are formed
  • the normal flow of production fluid from the well 16 and into the pipe 10 is terminated by closing the proper valves in the tree system 14, and the tubing 18 is installed in the pipe 10 in the manner discussed above.
  • One or more conventional pigging devices 40 are then inserted downwardly into the space 20 through the column of production fluid in the space. This insertion can be done in any conventional manner including installing the pigging devices 40 on the lower end portion of the tubing 18 before it is inserted in the pipe 10.
  • the pigging devices 40 are configured to normally allow fluids to flow past them in the space 20, but can be expanded to bridge across the space 20 in a conventional manner, thus creating a dynamic seal. It will be assumed that the pigging device 40 nearest to the production facility 12 (Fig. 1), which is the uppermost device as viewed in Fig. 6, is expanded and the remaining devices are configured to allow fluid to flow past them.
  • Gas from the production facility 12 is then introduced into the upper end of the tubing 18 and flows in the tubing in a direction shown by the arrows A, which is towards the well 16.
  • the gas displaces the production fluid in the tubing 18 which exits the lower end of the tubing, and flows in the space 20 in a direction shown by the arrows C, which is towards the production facility 12.
  • the displaced fluid and the gas flowing through the space 20 in the above manner will pass through all of the pigging devices 40 with the exception of the above device nearest to the production facility which will be pushed upwardly in the space by the gas and fluid.
  • As the latter pigging device 40 moves upwardly, it will sweep out the fluids above the space 20.
  • the remaining pigging devices 40 can be expanded as necessary and forced towards the production facility 12 in the above manner to remove the desired quantity of production fluid from the pipe.
  • the system is depressurized either via the space or by the tubing 18.
  • the remaining production fluid is allowed to expand and flow naturally to the production facility 12 via the tube 18 or by the space 20 by a variety of physical phenomena including the expansion of the relatively low vapor pressure production fluid and/or the vaporization of the high vapor pressure gas.
  • the pipe l0 can be further depressurized if desired by flowing the gas down the space 20 and upwardly through the tubing 18.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Pipeline Systems (AREA)

Abstract

L'invention concerne un système et un procédé permettant de réduire la pression hydraulique dans une canalisation raccordant un puits à un emplacement éloigné, consistant à introduire dans la canalisation une section de tube de manière à délimiter un espace entre le tube et la canalisation, et à introduire un fluide sous pression dans le tube de manière à déplacer le fluide dans le tube et à réduire la pression hydraulique dans la canalisation afin d'empêcher la formation d'hydrates dans la canalisation.
PCT/GB2005/001003 2004-03-19 2005-03-16 Systeme et procede permettant de remedier aux obstructions dans un pipe-line WO2006010874A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US10/804,545 2004-03-19
US10/804,545 US20050205261A1 (en) 2004-03-19 2004-03-19 System and method for remediating pipeline blockage

Publications (1)

Publication Number Publication Date
WO2006010874A1 true WO2006010874A1 (fr) 2006-02-02

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PCT/GB2005/001003 WO2006010874A1 (fr) 2004-03-19 2005-03-16 Systeme et procede permettant de remedier aux obstructions dans un pipe-line

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US (1) US20050205261A1 (fr)
WO (1) WO2006010874A1 (fr)

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