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US20120308408A1 - Subsea compression system for well stream boosting - Google Patents

Subsea compression system for well stream boosting Download PDF

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Publication number
US20120308408A1
US20120308408A1 US13/486,147 US201213486147A US2012308408A1 US 20120308408 A1 US20120308408 A1 US 20120308408A1 US 201213486147 A US201213486147 A US 201213486147A US 2012308408 A1 US2012308408 A1 US 2012308408A1
Authority
US
United States
Prior art keywords
pump
compressor
rotor
compression station
speed reduction
Prior art date
Legal status (The legal status 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 status listed.)
Abandoned
Application number
US13/486,147
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English (en)
Inventor
Odd Marius Rosvold
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Vetco Gray Scandinavia AS
Original Assignee
Vetco Gray Scandinavia AS
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 Vetco Gray Scandinavia AS filed Critical Vetco Gray Scandinavia AS
Assigned to VETCO GRAY SCANDINAVIA AS reassignment VETCO GRAY SCANDINAVIA AS ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: ROSVOLD, ODD MARIUS
Publication of US20120308408A1 publication Critical patent/US20120308408A1/en
Abandoned legal-status Critical Current

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Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
    • F04D13/00—Pumping installations or systems
    • F04D13/02—Units comprising pumps and their driving means
    • F04D13/06—Units comprising pumps and their driving means the pump being electrically driven
    • F04D13/08—Units comprising pumps and their driving means the pump being electrically driven for submerged use
    • F04D13/086—Units comprising pumps and their driving means the pump being electrically driven for submerged use the pump and drive motor are both submerged
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
    • F04D13/00—Pumping installations or systems
    • F04D13/02—Units comprising pumps and their driving means
    • F04D13/021—Units comprising pumps and their driving means containing a coupling
    • F04D13/022—Units comprising pumps and their driving means containing a coupling a coupling allowing slip, e.g. torque converter
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
    • F04D25/00—Pumping installations or systems
    • F04D25/02—Units comprising pumps and their driving means
    • F04D25/06—Units comprising pumps and their driving means the pump being electrically driven
    • F04D25/0686—Units comprising pumps and their driving means the pump being electrically driven specially adapted for submerged use
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04D—NON-POSITIVE-DISPLACEMENT PUMPS
    • F04D31/00—Pumping liquids and elastic fluids at the same time

Definitions

  • Embodiments of the present invention relate to a subsea compression system for well stream boosting by compression of gas and pumping of liquid in subsea hydrocarbon production. More precisely, embodiments of the present invention relate to arrangements on a compressor station forming part of a subsea compression system.
  • Offshore gas production involves installations on the seabed which are controlled and powered from a land-based or sea-based terminal or host facility.
  • Well fluid is transported via pipelines from a subsea production system to the receiving terminal to be further processed before the products are supplied to market.
  • the fluid reservoir pressure is usually sufficient for feeding the hydrocarbon fluids through the pipeline.
  • boosting of fluid pressure and flow may be required at one or more compression stations along the feed line in order to maintain flow rate and production level.
  • Compressors used in subsea compression stations are adapted to process wet gas containing a certain ratio of liquid. Above such a ratio, liquid pumps will be required.
  • well fluid containing gas and liquid enters a separator or scrubber in which liquid is separated from the well stream and fed to the pump, providing predictable operating points for both the compressor and the pump with respect to liquid volume fraction.
  • the pump is operated to pump the liquid downstream, typically by injecting the liquid into the compressed gas that is discharged from the compressor, whereby a re-mixed multiphase well fluid leaves the compression station at a raised pressure level and flow.
  • the subsea compression station may optionally be arranged for discharge of boosted gas and liquid flows via separate export lines.
  • each compressor and pump is driven by a dedicated electrical motor respectively which is supplied operating and control power via an umbilical connecting the compression station with its host facility.
  • Each compressor or pump motor in the compression station requires for its operation an individual setup of power and control gear for a variable speed drive, such as subsea switchgear, wet-mate electrical connectors, high voltage electrical jumpers and electrical control system components, cooling and lubricating circuits including valves and flow or pressure control, etc.
  • a subsea compression station comprises a separator, a compressor configured to compress and discharge gas separated from a well stream ingested into the separator, a pump configured to pump liquid separated from the well stream, and an electrical motor drivingly connected to a compressor rotor comprising a compressor rotor shaft connectable to a pump rotor through a speed reduction device, wherein the speed reduction device is configured to bring the pump rotor in co-rotation with the compressor rotor at a reduced speed.
  • FIG. 1 is a diagram illustrating schematically the setup of a prior art subsea compressions station
  • FIG. 2 is a diagram corresponding to FIG. 1 , illustrating the setup of a subsea compression station according to an embodiment of the present invention
  • FIG. 3 is sectional view showing an embodiment of the present invention.
  • FIG. 4 is a corresponding sectional view showing an embodiment of the present invention.
  • FIG. 5 is a sectional view showing an embodiment of the present invention.
  • FIG. 6 is a simplified diagram illustrating an implementation of an embodiment of the present invention.
  • the compression station receives bi-phase or multi-phase well fluid from at least one subsea production system and feeds boosted well fluid into one or several export pipe lines for further transport to a receiving terminal.
  • the compression station comprises a compressor module including one or more compressors 1 , a pump module including at least one pump 2 , and a separator/scrubber module including a separator 3 .
  • the separator 3 is designed for liquid/gas separation and may additionally be structured for dissolving liquid slugs, for hydrate prevention and for sorting out solid particles entrained in the well stream, for gas scrubbing etc., so that compressible gas (wet gas) is delivered to the compressor intake.
  • the compressor(s) 1 is designed for raising the pressure of the gas and discharging the gas at an elevated pressure into the export pipeline.
  • the pump(s) 2 is designed for injecting the excess liquid, at an elevated pressure, to the gas flow discharged from the compressor.
  • High voltage power, low voltage power, hydraulic, control and utilities are supplied from the host facility via an umbilical connected to the subsea compression station.
  • Utility and control power is distributed to consumers on the subsea compression station via transformers, high voltage cables and wet-mate electrical connectors, switchgear, electrical jumpers, circuit breaker modules, etc. Since the compressor(s) 1 and pump(s) 2 are individually driven by dedicated variable speed drive (VSD) electrical motors 4 and 5 , respectively, utility and control power equipment needs to be individually installed for each motor.
  • VSD variable speed drive
  • the dedicated utility and control power equipment is schematically represented through VSD-blocks 6 .
  • each motor requires separate flexible couplings, guiding and landing devices, valves and fluid lines for cooling, lubrication and barrier pressure, on the subsea compression station.
  • FIG. 2 is an overview of a subsea compression station which utilizes embodiments of the present invention.
  • a noticeable difference in the architecture of FIG. 2 is the significantly reduced number of VSD-blocks 6 .
  • the number of VSD-blocks 6 is reduced by 50% as the result of driving the pump(s) 2 with the compressor motor(s) 4 , by way of the compressor rotor shaft 7 and an interconnected speed reduction device 8 , which brings the pump rotor in co-rotation with the compressor rotor at reduced speed.
  • the dedicated pump motor and associated components such as power supply components, operation control, lubrication and cooling components etc.
  • the dedicated pump motor and associated components can be omitted which substantially reduces cost and complexity of the compression station.
  • the reduction in the number of components required in the subsea compression station applies to all components that would otherwise have been involved in the operation of the omitted motor.
  • the speed reduction required between the compressor the compressor rotor shaft and the pump can be accomplished in alternative ways.
  • a mechanical clutch and gear reduction may be used as coupling and speed reduction device.
  • a mechanical clutch coupling would however require slowing down the drive motor and compressor in order to connect the pump rotor to the compressor rotor, which revolves at considerably higher speed than the pump rotor in normal operating conditions.
  • FIG. 3 illustrates an embodiment of the invention, relying on a speed reduction device in the form of a variable speed, hydrodynamic torque converter 9 .
  • the compressor rotor shaft 7 is fixedly connected to a housing 10 of a fill-controlled hydrodynamic torque converter 9
  • the pump rotor 11 is fixedly connected to the turbine 12 of the fill-controlled torque converter 9 .
  • the amount of torque and output speed that is transferred from the compressor rotor shaft 7 to the pump rotor 11 depends on the fill level of hydraulic fluid in the housing 10 , which can be controlled and modified during operation. For a slow start of the pump, acceleration of pump rotor 11 can be controlled through the speed by which the housing 10 is filled, and the appropriate speed reduction is achieved through a corresponding fill level in the housing 1 .
  • the compressor rotor shaft 7 may be fixedly connected to an impeller 13 of a variable vane hydrodynamic torque converter 14
  • the pump rotor 11 is fixedly connected to the turbine 15 of the variable vane hydrodynamic torque converter 14 .
  • the amount of torque and output speed that is transferred from the compressor rotor shaft 7 to the pump rotor 11 depends on the angle of attack of guide vanes 16 adjustably arranged on a stator 17 in which the impeller is housed.
  • the guide vanes 16 can be controlled and modified during operation through actuation of a vane angle shifting mechanism 18 on the stator.
  • FIG. 5 illustrates another embodiment of the invention. This embodiment utilizes an electrical hysteresis powered clutch 19 to reduce the speed that is transferred from the compressor rotor shaft 7 to the pump rotor 11 .
  • the compressor rotor shaft 7 is fixedly connected to a rotor 20 of the electrical hysteresis powered clutch 19
  • the pump rotor 11 is fixedly connected to a hysteresis disk 21 of the electrical clutch 19 .
  • the hysteresis disk 21 passes an annular gap in the rotor 20 without physical contact between disk 21 and rotor 20 .
  • the rotor 20 rotates in a magnetic field created as current/voltage is applied to an electromagnet 22 near the rotor. As the rotor 20 rotates, the hysteresis disk 21 is pulled in rotation in result of magnetic drag between the rotor 20 and the hysteresis disk 21 .
  • the amount of torque and output speed that is transferred from the compressor rotor shaft 7 to the pump rotor 11 depends on the amount of current/voltage that is applied to the electromagnet 22 , which can be controlled and modified during operation.
  • FIG. 6 A subsea compression station laid out in accordance with the common-drive and individual control concept provided by embodiments of the present invention is illustrated schematically in FIG. 6 .
  • a fully equipped and operative subsea compression station typically comprises import and export well stream manifolds and valves, flow and pressure meters, re-circulation lines and valves, anti-surge control circuit and valves, lubrication and barrier fluid circuits and valves, umbilical head end, transformers, coolers, sand trap etc., and other equipment which is conventionally found on a subsea compression station.
  • import and export well stream manifolds and valves typically comprises import and export well stream manifolds and valves, flow and pressure meters, re-circulation lines and valves, anti-surge control circuit and valves, lubrication and barrier fluid circuits and valves, umbilical head end, transformers, coolers, sand trap etc., and other equipment which is conventionally found on a subsea compression station.
  • FIG. 6 For reasons of clarity, the detailed structure and organization of modules and units which are of subordinated significance have been excluded from FIG. 6 .
  • well fluid F is fed into a separator and slug catcher 3 configured for separation of gas and liquid.
  • the separator 3 houses a mixer pipe 23 wherein gas and remaining liquid are evenly distributed before delivery to the intake of compressor 1 via wet gas fluid line 24 .
  • the level of liquid in the separator 3 is controlled through drain pipe 25 from which excess liquid is withdrawn and delivered to pump 2 via self-filling liquid line 26 .
  • the compressor 1 and pump 2 are commonly driven by a single, variable speed electrical motor 4 , the output torque and speed of which is reduced by means of a speed reduction device 8 interconnected between the pump 2 and the compressor 1 .
  • Utility and control power is supplied to the motor 4 via VSD-block 6 and umbilical head end block 27 representing the necessary high and low voltage circuits, wet mate connectors, switchgear, circuit breakers, etc.
  • Operating fluid or pressure for the fill-controlled torque converter, or control power for the variable vane torque converter, or magnetizing current/voltage for the electrical hysteresis clutch, as required in each respective embodiment, is supplied to the speed reduction device 8 from the host facility/top side terminal via power supply line 28 .
  • Control of power supply for actuation of the speed reduction device 8 is accomplished in response to a detected liquid fraction or level in the separator 3 and communicated to actuator valves or actuator switches in the speed reduction device via pilot line 29 .
  • the compressor(s) used in the subsea compression station is designed for a substantial elevation of the gas pressure, for example, from about 40 bar at compressor intake to about 120 bar at compressor discharge.
  • Heavy duty centrifugal wet gas compressors are generally utilized, typically operating at a power range of one or several tens of megawatt and at rotational speeds in the order of 8-12,000 rev per min.
  • the pump(s) used in the subsea compression station is designed for boosting the liquid stream up to a pressure required for introduction into the gas discharged from the compressor.
  • Positive displacement pumps are useful in this connection, operating at a power range of hundreds of kilowatt and at rotational speeds of about 1,500-4,000 rev per min. Thus, in most compressor/pump combinations a speed reduction ratio of about 4-5:1 will be appropriate. However, positive displacement pumps or centrifugal pumps rotating at other operational speeds may alternatively be used, requiring different speed reduction ratios.
  • the present invention provides great freedom in the choice of pump/compressor combination since both the fill-controlled or variable vane hydrodynamic torque converters as well as the electrical hysteresis clutch can be controlled between zero and 100% lockup between driving and driven components, depending obviously on the output torque required.
  • element 7 shall be understood to include any shaft or axle that is connectable to or constitutes an integrally formed extension from the compressor rotor and which co-rotates with the compressor rotor.
  • element 11 shall be understood to include any shaft or axle that is connectable to or constitutes an integrally formed extension from the pump rotor and which co-rotates with the pump rotor.
  • Embodiments of the present invention are not limited to the in-line, co-axial assembly which is schematically illustrated in the drawings. Instead, the pump and compressor may alternatively be arranged on parallel axes, or even on crossing axes, with intermeshing gears or bevel gears transmitting torque and rotation from the compressor motor to the pump rotor.

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Structures Of Non-Positive Displacement Pumps (AREA)
US13/486,147 2011-06-01 2012-06-01 Subsea compression system for well stream boosting Abandoned US20120308408A1 (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NO20110801A NO334554B1 (no) 2011-06-01 2011-06-01 Undersjøisk kompresjonssystem for trykkøkning av brønnstrøm
NO20110801 2011-06-01

Publications (1)

Publication Number Publication Date
US20120308408A1 true US20120308408A1 (en) 2012-12-06

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US (1) US20120308408A1 (no)
EP (1) EP2530326A2 (no)
AU (1) AU2012203224A1 (no)
BR (1) BR102012013163A2 (no)
NO (1) NO334554B1 (no)

Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20150322756A1 (en) * 2012-09-12 2015-11-12 Christopher E. Cunningham Subsea Multiphase Pump or Compressor with Magnetic Coupling and Cooling or Lubrication by Liquid or Gas Extracted from Process Fluid
US20160145980A1 (en) * 2013-03-15 2016-05-26 Fmc Technologies, Inc. Submersible Well Fluid System
US20160333677A1 (en) * 2015-05-11 2016-11-17 Fuglesangs Subsea As Omnirise hydromag "variable speed magnetic coupling system for subsea pumps"
US20170184131A1 (en) * 2014-05-30 2017-06-29 Nuovo Pignone Srl System and method for draining a wet-gas compressor
US9879663B2 (en) * 2013-03-01 2018-01-30 Advanced Cooling Technologies, Inc. Multi-phase pump system and method of pumping a two-phase fluid stream
US9954414B2 (en) 2012-09-12 2018-04-24 Fmc Technologies, Inc. Subsea compressor or pump with hermetically sealed electric motor and with magnetic coupling
US10161418B2 (en) 2012-09-12 2018-12-25 Fmc Technologies, Inc. Coupling an electric machine and fluid-end
US10801309B2 (en) 2012-09-12 2020-10-13 Fmc Technologies, Inc. Up-thrusting fluid system
NO20190801A1 (en) * 2019-06-26 2020-12-28 Fsubsea As System for subsea pressure booster power supply and distribution

Families Citing this family (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2015018945A2 (en) 2013-08-09 2015-02-12 Linde Aktiengesellschaft Subsea well stream treatment
NO339899B1 (en) 2015-05-14 2017-02-13 Vetco Gray Scandinavia As A control system for controlling a subsea gas compression system
DE102015226640A1 (de) * 2015-12-23 2017-06-29 Voith Patent Gmbh Unterwasser-Antriebseinheit
WO2018077527A1 (en) * 2016-10-24 2018-05-03 Sulzer Management Ag Multiphase pump and method for operating such a pump
NO345311B1 (en) * 2018-04-26 2020-12-07 Fsubsea As Pressure booster with integrated speed drive
EP3730795A1 (en) * 2019-04-23 2020-10-28 Sulzer Management AG Process fluid lubricated pump

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US5471848A (en) * 1994-01-05 1995-12-05 Major; Thomas O. Refrigerant recovery and purification method and apparatus
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US20090260367A1 (en) * 2005-12-23 2009-10-22 Martin William L Multi-Compressor String With Multiple Variable Speed Fluid Drives
US7819950B2 (en) * 2003-09-12 2010-10-26 Kvaerner Oilfield Products A.S. Subsea compression system and method

Patent Citations (8)

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US4686822A (en) * 1984-01-31 1987-08-18 Bbc Brown, Boveri & Company Limited Gas turbine power station with air storage and method for operating the same
US5238095A (en) * 1992-06-30 1993-08-24 Pedu Jeffrey C Hysteresis brakes and clutches
US5471848A (en) * 1994-01-05 1995-12-05 Major; Thomas O. Refrigerant recovery and purification method and apparatus
US6584784B2 (en) * 1999-02-05 2003-07-01 Midwest Research Institute Combined refrigeration system with a liquid pre-cooling heat exchanger
US7819950B2 (en) * 2003-09-12 2010-10-26 Kvaerner Oilfield Products A.S. Subsea compression system and method
US20070068759A1 (en) * 2004-05-14 2007-03-29 Bernd Koppitz Hydrodynamic torque converter
US7353924B2 (en) * 2004-12-23 2008-04-08 Zf Friedrichshafen Ag Hydrodynamic torque converter
US20090260367A1 (en) * 2005-12-23 2009-10-22 Martin William L Multi-Compressor String With Multiple Variable Speed Fluid Drives

Cited By (17)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US10801309B2 (en) 2012-09-12 2020-10-13 Fmc Technologies, Inc. Up-thrusting fluid system
US10393115B2 (en) * 2012-09-12 2019-08-27 Fmc Technologies, Inc. Subsea multiphase pump or compressor with magnetic coupling and cooling or lubrication by liquid or gas extracted from process fluid
US20150322756A1 (en) * 2012-09-12 2015-11-12 Christopher E. Cunningham Subsea Multiphase Pump or Compressor with Magnetic Coupling and Cooling or Lubrication by Liquid or Gas Extracted from Process Fluid
US10161418B2 (en) 2012-09-12 2018-12-25 Fmc Technologies, Inc. Coupling an electric machine and fluid-end
US9954414B2 (en) 2012-09-12 2018-04-24 Fmc Technologies, Inc. Subsea compressor or pump with hermetically sealed electric motor and with magnetic coupling
US9879663B2 (en) * 2013-03-01 2018-01-30 Advanced Cooling Technologies, Inc. Multi-phase pump system and method of pumping a two-phase fluid stream
US10221662B2 (en) * 2013-03-15 2019-03-05 Fmc Technologies, Inc. Submersible well fluid system
US20160145980A1 (en) * 2013-03-15 2016-05-26 Fmc Technologies, Inc. Submersible Well Fluid System
US11352863B2 (en) 2013-03-15 2022-06-07 Fmc Technologies, Inc. Submersible well fluid system
US12480390B2 (en) 2013-03-15 2025-11-25 Fmc Technologies, Inc. Submersible well fluid system
US20170184131A1 (en) * 2014-05-30 2017-06-29 Nuovo Pignone Srl System and method for draining a wet-gas compressor
US10801522B2 (en) * 2014-05-30 2020-10-13 Nuovo Pignone Srl System and method for draining a wet-gas compressor
US10151318B2 (en) 2015-05-11 2018-12-11 Fuglesangs Subsea SA Omnirise hydromag “variable speed magnetic coupling system for subsea pumps”
US9964113B2 (en) * 2015-05-11 2018-05-08 Fuglesangs Subsea As Omnirise hydromag “variable speed magnetic coupling system for subsea pumps”
US20160333677A1 (en) * 2015-05-11 2016-11-17 Fuglesangs Subsea As Omnirise hydromag "variable speed magnetic coupling system for subsea pumps"
NO20190801A1 (en) * 2019-06-26 2020-12-28 Fsubsea As System for subsea pressure booster power supply and distribution
US12146485B2 (en) 2019-06-26 2024-11-19 Fsubsea As System for subsea pressure booster power supply and distribution, method for operation and use thereof

Also Published As

Publication number Publication date
BR102012013163A2 (pt) 2014-12-09
NO20110801A1 (no) 2012-12-03
AU2012203224A1 (en) 2012-12-20
EP2530326A2 (en) 2012-12-05
NO334554B1 (no) 2014-04-07

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Owner name: VETCO GRAY SCANDINAVIA AS, NORWAY

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:ROSVOLD, ODD MARIUS;REEL/FRAME:028423/0131

Effective date: 20120604

STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION