WO2007073195A1 - Pump unit and method for pumping a well fluid - Google Patents

Pump unit and method for pumping a well fluid Download PDF

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Publication number
WO2007073195A1
WO2007073195A1 PCT/NO2006/000430 NO2006000430W WO2007073195A1 WO 2007073195 A1 WO2007073195 A1 WO 2007073195A1 NO 2006000430 W NO2006000430 W NO 2006000430W WO 2007073195 A1 WO2007073195 A1 WO 2007073195A1
Authority
WO
WIPO (PCT)
Prior art keywords
pump
well fluid
fluid
motor
conditioning unit
Prior art date
Application number
PCT/NO2006/000430
Other languages
French (fr)
Inventor
Ola SKRØVSETH
Karl Olav Haram
Original Assignee
Norsk Hydro Produksjon A.S.
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 Norsk Hydro Produksjon A.S. filed Critical Norsk Hydro Produksjon A.S.
Publication of WO2007073195A1 publication Critical patent/WO2007073195A1/en

Links

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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • E21B43/121—Lifting well fluids
    • E21B43/128—Adaptation of pump systems with down-hole electric drives
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/35—Arrangements for separating materials produced by the well specially adapted for separating solids
    • 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
    • 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
    • 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
    • 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
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/36—Underwater separating arrangements

Definitions

  • the present invention relates to a subsea pump system for well fluid boosting by pumping hydrocarbon fluids. More particularly, the invention relates to a pump with a liquid conditioning unit for conditioning a liquid fraction of a well stream.
  • the conditioning unit conditions the liquid to make it suitable for use in mechanical bearings.
  • the system is for instance suited to be used in connection with magnetic bearings and high speed motor.
  • the system is particularly developed for deep sea compression stations.
  • An offshore gas field may be developed with seabed installations which are tied back to terminals onshore or to an existing platform.
  • the seabed installation comprises one or more production templates where each template produces well fluids through manifold headers which are connected to one or more pipelines.
  • the pipelines transport well fluids to an onshore terminal, an existing platform or any other receiving facility for further processing.
  • Processed gas and condensate are exported to the market.
  • One or more umbilicals for power, control and utility supplies are installed from the receiving facility to the subsea installation.
  • well fluids may flow into the receiving facility by means of the reservoir pressure. Later in the productions phase or at start-up of the production, well fluid pressure boosting is required in order to maintain the production level and to recover the anticipated gas and condensate volumes. This may be performed by subsea compressors and pump assemblies.
  • Subsea fluid pressure boosting assemblies for this purpose with electric motors that requires a dry environment, and that utilizes a pressurised, gas filled motor housing are for instance disclosed in Norwegian Patents Nos. NO 172075, NO 173197, Norwegian Patent Application No. 2001 5199 as well as Norwegian Patent Application No. 2003 3034.
  • Norwegian Patent Application 2003 3034 discloses a gas compressor module with, pressure housing.
  • the module includes an electric motor and a compressor connected with at least one shaft.
  • the shaft is carried by magnetic bearings.
  • the application describes volume and pressure control of the gas flowing into the motor, and the use of a supply of dry hydrocarbon gas.
  • the application does not describe how to accommodate and solve the problem with high-speed requirements for a high pressure multistage pump unit.
  • the need for a lubricating oil is omitted as the unit may utilize magnetic bearings and the use of a gear box or transmission that traditionally is lubricated with oil, and that accordingly potentially may leak, is omitted by the use of a high speed motor.
  • the reduction of the number of movable components by omitting a gear box also reduces the number of parts that may fail.
  • a pump unit comprising a pump with a pump shaft, in a pump housing for pumping a well fluid.
  • a motor with a motor shaft is adapted to drive the pump.
  • the motor is placed in a motor housing.
  • At least one magnetic bearing for supports at least one of the shafts, and in this case, the magnetic bearing is one out of several bearings. However, in many cases all the major bearings in the unit will be magnetic bearings to fully utilize the advantages of this type of bearings.
  • At least one mechanical seal in some cases placed in a sealing chamber, seales around at least one of the shafts.
  • the sealing chamber may be used to transfer the sealing fluid to the seal.
  • a fluid connection may lead the fluid to the sealing chamber or directly to the mechanical seal.
  • the pump may further comprise at least one conditioning unit connected to an outlet or an intermediate stage of the pump for removing contaminations in at least a part of the well fluid.
  • the pressure may be taken from a source delivering a suitable pressure to omit a pressure regulator. It may be provided a fluid connection between the seal or sealing chamber and the conditioning unit, adapted to lead conditioned well fluid from the conditioning unit to the sealing.
  • the motor may be a high speed motor with a direct drive of the pump to omit a gear box.
  • the conditioning unit may include at least one hydrocyclone with particle removing features, and a fluid connection between the at least one hydro cyclone and the inlet side of the pump, for leading the removed particles to the inlet side of the pump.
  • hydro cyclones may however be necessary for sufficient capacity and cleaning.
  • a method for preventing ingress of unconditioned well fluid in at least one seal or sealing chamber of a pump for pumping unconditioned well fluid may include leading a well fluid from a well to a pump, pumping the well fluid with the pump, leading a fraction of the well fluid from an outlet or an intermediate step of the pump to a conditioning unit, conditioning the well fluid with the conditioning unit to remove contaminations in the well fluid, and leading the well fluid from the conditioning unit to the at least one seal to displace contaminated well fluid.
  • the invention may include a high-speed motor that may be gas or fluid filled.
  • a mechanical seal of a suitable type may separate the motor and the pump and may be flushed with the conditioned well fluid.
  • a mechanical seal is typically a unit that includes one or several chambers with an obstruction or sealing element formed by a rotating ring and a stationary ring. If the motor is a gas filled motor, the seals may be sealing the motor to prevent ingress of the liquid surrounding the motor.
  • a separate liquid such as TEG, oil etc. or a medium from the pump may be used. If this medium includes contaminations and impurities, it must be conditioned to avoid unnecessary wear.
  • the well fluid may lead to considerable erosion and rapid degradation of seals, shafts and bearings.
  • the high speed motor in this context may be a motor that runs faster than a two pole motor at a mains input frequency, that is above 3600 rpm at 60Hz and 3000 rpm at 50 Hz.
  • a subsea compression station where this system may be included may comprise the following modules and parts: one or more compressor trains and pump modules, one or more circuit breaker modules, inlet and outlet manifolds, inlet coolers (if supply pipelines not are sufficient for cooling the well stream), inlet sand trap (for accidental sand production), parking location for main transformer and power umbilical termination head, process system, control system.
  • the pump train may include: pump module, pump variable speed drive (VSD), (variable speed drive), remote and manually operated valves, interconnection piping, control system including control modules.
  • the pump may be driven directly by high-speed motor.
  • the electric motor may be cooled with a hydrocarbon gas or a fluid.
  • the system may utilize magnetic radial and axial bearings for each of the subsea pump modules, as well as rundown bearings.
  • the pump system may be designed to handle the continuous fines/sand production.
  • the rotating equipment may be protected against wear and degradation from solids to ensure high efficiency, long life and reliability.
  • the conditioning unit separates solids from the liquid, which in turn is supplied to the sealing chambers.
  • the pump station may have tie-in connections for well fluid discharge, and may include ROV operated valves for routing of the well fluid to the different pipelines.
  • the well fluid from tied-in production templates may be distributed to a separator equipped with remotely actuated isolation valve in the inlet pipe. Most of the solids from the production may be removed in separators.
  • Sand/fines/solids entering the pump station may be separated out in the separators and transported via the liquid pump to the discharge pipeline.
  • Fig. 1 is a schematic representation of a sub sea pump module according to an embodiment of the invention.
  • Fig. 1 shows a subsea pump module according to an embodiment of the o invention.
  • the module includes a pressure chamber 1 for an electric motor, a coupling or intermediate chamber 2, and a pressure chamber 4 for a pump.
  • the motor in the pressure chamber 1 is connected to the pump in the pressure chamber 4 with a coupling 3 in the coupling chamber 2.
  • the motor and the pump may be connected to the same shaft.
  • the coupling 3 may for 5 instance be a flange or any other suitable joint.
  • the coupling chamber 2 may include a transmission if a certain ratio is needed between the motor and the pump.
  • the motor may be a high-speed motor such that a gear box not is needed.
  • the shaft 11 of the motor is supported in bearings 12, in some cases placed in bearing chambers, and the shaft 13 of the pump is supported in these bearings 12.
  • the shafts may typically support rotors.
  • the bearings may be magnetic bearings.
  • An outlet conditioning unit 8 receives a flow from an outlet 7 of the pump and delivers a conditioned liquid to the mechanical seals 5, in some cases placed in sealing chambers.
  • the sealing chambers may, as mentioned, be sealed with mechanical seals.
  • the mechanical seals, in some cases placed in sealing chambers may be supplied with oil or TEG from a separate source. In o this case the conditioning unit 8 is omitted.
  • the pump may be a multistage pump, and the liquid to the conditioning unit 8 may be taken from an intermediate stage of the pump.
  • a line 14 from the conditioning unit 8 supplies liquid from the conditioning unit 8 and into the mechanical seals 5 of the pump.
  • the pump delivers a compressed outlet fluid flow through line 7.
  • the pump has an inlet line 6.
  • the pressure chamber 1 housing the motor includes electric connections 10. Bearing chambers may be sealed from the liquid such that canned bearings not necessarily must be used.
  • the bearing chambers may include connections for bearing coils for the magnetic bearings and sensors.
  • the conditioning unit 8 may typically include one or several hydrocyclones with arrangements to remove particles such as sand etc. The removed particles may be returned to the suction side of the pump for being brought further into the flow of well fluid.
  • the pump is typically used to pressurize the well flow to a certain pressure.
  • the pump may typically be a multistage pump.

Landscapes

  • 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)
  • General Engineering & Computer Science (AREA)
  • Structures Of Non-Positive Displacement Pumps (AREA)

Abstract

The present invention concerns a pump unit comprising a pump with a pump shaft (13), in a pump housing for pumping a well fluid. A motor with a motor shaft (11) for driving the pump is placed in a motor housing (1). At least one magnetic bearing supports at least one of the shafts (11, 13), and at least one mechanical seal (5), seals around at least one of the shafts (11, 13). A fluid connection (14) leads a fluid to the at least one mechanical seal (5). A method for preventing ingress of unconditioned well fluid in a sealing chamber is also disclosed.

Description

PUMP UNIT AND METHOD FOR PUMPING A WELL FLUID
The present invention relates to a subsea pump system for well fluid boosting by pumping hydrocarbon fluids. More particularly, the invention relates to a pump with a liquid conditioning unit for conditioning a liquid fraction of a well stream. The conditioning unit conditions the liquid to make it suitable for use in mechanical bearings. The system is for instance suited to be used in connection with magnetic bearings and high speed motor.
The system is particularly developed for deep sea compression stations.
An offshore gas field may be developed with seabed installations which are tied back to terminals onshore or to an existing platform. The seabed installation comprises one or more production templates where each template produces well fluids through manifold headers which are connected to one or more pipelines. The pipelines transport well fluids to an onshore terminal, an existing platform or any other receiving facility for further processing. Processed gas and condensate are exported to the market. One or more umbilicals for power, control and utility supplies are installed from the receiving facility to the subsea installation.
For the initial production phase, well fluids may flow into the receiving facility by means of the reservoir pressure. Later in the productions phase or at start-up of the production, well fluid pressure boosting is required in order to maintain the production level and to recover the anticipated gas and condensate volumes. This may be performed by subsea compressors and pump assemblies.
Subsea fluid pressure boosting assemblies for this purpose with electric motors that requires a dry environment, and that utilizes a pressurised, gas filled motor housing are for instance disclosed in Norwegian Patents Nos. NO 172075, NO 173197, Norwegian Patent Application No. 2001 5199 as well as Norwegian Patent Application No. 2003 3034.
These publications disclose the use of gas filled electric motors where avoiding corrosion and other problems that are related to separation of hydrocarbon condensates and water in liquid form in the motor, is considered.
Norwegian Patent Application 2003 3034 discloses a gas compressor module with, pressure housing. The module includes an electric motor and a compressor connected with at least one shaft. The shaft is carried by magnetic bearings. The application describes volume and pressure control of the gas flowing into the motor, and the use of a supply of dry hydrocarbon gas.
Furthermore means for sensing the pressure in the inlet and outlet is described, whereby based on the measured pressure, the pressure and volume regulator controls the pressure for injection of gas from the supply into the motor housing.
The application does not describe how to accommodate and solve the problem with high-speed requirements for a high pressure multistage pump unit.
According to one embodiment of the invention, the need for a lubricating oil is omitted as the unit may utilize magnetic bearings and the use of a gear box or transmission that traditionally is lubricated with oil, and that accordingly potentially may leak, is omitted by the use of a high speed motor. The reduction of the number of movable components by omitting a gear box also reduces the number of parts that may fail.
This is achieved with the system according to the present invention defining a pump unit comprising a pump with a pump shaft, in a pump housing for pumping a well fluid. A motor with a motor shaft is adapted to drive the pump. The motor is placed in a motor housing. At least one magnetic bearing for supports at least one of the shafts, and in this case, the magnetic bearing is one out of several bearings. However, in many cases all the major bearings in the unit will be magnetic bearings to fully utilize the advantages of this type of bearings. At least one mechanical seal in some cases placed in a sealing chamber, seales around at least one of the shafts. The sealing chamber may be used to transfer the sealing fluid to the seal. A fluid connection may lead the fluid to the sealing chamber or directly to the mechanical seal.
The pump may further comprise at least one conditioning unit connected to an outlet or an intermediate stage of the pump for removing contaminations in at least a part of the well fluid. The pressure may be taken from a source delivering a suitable pressure to omit a pressure regulator. It may be provided a fluid connection between the seal or sealing chamber and the conditioning unit, adapted to lead conditioned well fluid from the conditioning unit to the sealing.
The motor may be a high speed motor with a direct drive of the pump to omit a gear box.
The conditioning unit may include at least one hydrocyclone with particle removing features, and a fluid connection between the at least one hydro cyclone and the inlet side of the pump, for leading the removed particles to the inlet side of the pump. Several hydro cyclones may however be necessary for sufficient capacity and cleaning.
A method for preventing ingress of unconditioned well fluid in at least one seal or sealing chamber of a pump for pumping unconditioned well fluid may include leading a well fluid from a well to a pump, pumping the well fluid with the pump, leading a fraction of the well fluid from an outlet or an intermediate step of the pump to a conditioning unit, conditioning the well fluid with the conditioning unit to remove contaminations in the well fluid, and leading the well fluid from the conditioning unit to the at least one seal to displace contaminated well fluid.
The invention may include a high-speed motor that may be gas or fluid filled. A mechanical seal of a suitable type may separate the motor and the pump and may be flushed with the conditioned well fluid.
A mechanical seal is typically a unit that includes one or several chambers with an obstruction or sealing element formed by a rotating ring and a stationary ring. If the motor is a gas filled motor, the seals may be sealing the motor to prevent ingress of the liquid surrounding the motor.
To maintain cooling of the faces between the rings it is used either a separate liquid such as TEG, oil etc. or a medium from the pump may be used. If this medium includes contaminations and impurities, it must be conditioned to avoid unnecessary wear. The well fluid may lead to considerable erosion and rapid degradation of seals, shafts and bearings.
The high speed motor in this context may be a motor that runs faster than a two pole motor at a mains input frequency, that is above 3600 rpm at 60Hz and 3000 rpm at 50 Hz.
A subsea compression station where this system may be included may comprise the following modules and parts: one or more compressor trains and pump modules, one or more circuit breaker modules, inlet and outlet manifolds, inlet coolers (if supply pipelines not are sufficient for cooling the well stream), inlet sand trap (for accidental sand production), parking location for main transformer and power umbilical termination head, process system, control system. The pump train may include: pump module, pump variable speed drive (VSD), (variable speed drive), remote and manually operated valves, interconnection piping, control system including control modules.
The pump may be driven directly by high-speed motor. The electric motor may be cooled with a hydrocarbon gas or a fluid. The system may utilize magnetic radial and axial bearings for each of the subsea pump modules, as well as rundown bearings.
The pump system may be designed to handle the continuous fines/sand production. The rotating equipment may be protected against wear and degradation from solids to ensure high efficiency, long life and reliability.
The conditioning unit separates solids from the liquid, which in turn is supplied to the sealing chambers.
The pump station may have tie-in connections for well fluid discharge, and may include ROV operated valves for routing of the well fluid to the different pipelines.
The well fluid from tied-in production templates may be distributed to a separator equipped with remotely actuated isolation valve in the inlet pipe. Most of the solids from the production may be removed in separators.
Sand/fines/solids entering the pump station may be separated out in the separators and transported via the liquid pump to the discharge pipeline.
However, a sand trap for accidental sand production may be used to remove sand from the inlet well fluid. Brief description of the enclosed drawing:
Fig. 1 is a schematic representation of a sub sea pump module according to an embodiment of the invention.
5
Detailed description of embodiments of the invention with reference to the enclosed figure:
Fig. 1 shows a subsea pump module according to an embodiment of the o invention. The module includes a pressure chamber 1 for an electric motor, a coupling or intermediate chamber 2, and a pressure chamber 4 for a pump. The motor in the pressure chamber 1 is connected to the pump in the pressure chamber 4 with a coupling 3 in the coupling chamber 2. Alternatively the motor and the pump may be connected to the same shaft. The coupling 3 may for 5 instance be a flange or any other suitable joint. Alternatively the coupling chamber 2 may include a transmission if a certain ratio is needed between the motor and the pump. However, the motor may be a high-speed motor such that a gear box not is needed.
0 The shaft 11 of the motor is supported in bearings 12, in some cases placed in bearing chambers, and the shaft 13 of the pump is supported in these bearings 12. The shafts may typically support rotors. The bearings may be magnetic bearings.
5 An outlet conditioning unit 8 receives a flow from an outlet 7 of the pump and delivers a conditioned liquid to the mechanical seals 5, in some cases placed in sealing chambers. The sealing chambers may, as mentioned, be sealed with mechanical seals. Alternatively, the mechanical seals, in some cases placed in sealing chambers, may be supplied with oil or TEG from a separate source. In o this case the conditioning unit 8 is omitted. The pump may be a multistage pump, and the liquid to the conditioning unit 8 may be taken from an intermediate stage of the pump. A line 14 from the conditioning unit 8 supplies liquid from the conditioning unit 8 and into the mechanical seals 5 of the pump.
The pump delivers a compressed outlet fluid flow through line 7.
The pump has an inlet line 6.
The pressure chamber 1 housing the motor includes electric connections 10. Bearing chambers may be sealed from the liquid such that canned bearings not necessarily must be used. The bearing chambers may include connections for bearing coils for the magnetic bearings and sensors.
The conditioning unit 8 may typically include one or several hydrocyclones with arrangements to remove particles such as sand etc. The removed particles may be returned to the suction side of the pump for being brought further into the flow of well fluid.
Fluid leaking out of the seals should be brought back to the suction side of the pump.
The pump is typically used to pressurize the well flow to a certain pressure.
The pump may typically be a multistage pump.

Claims

Claims:
1. A pump unit comprising a pump with a pump shaft (13), in a pump housing (4) for pumping a well fluid; a motor with a motor shaft (11) for driving the pump, in a motor housing
(1); at least one magnetic bearing (12) for supporting at least one of the shafts (11 , 13); at least one mechanical seal (5) for sealing around at least one of the shafts (11 , 13); and a fluid connection (14) for leading a fluid to the at least one mechanical seal (5).
2. The pump unit according to claim 1 , further comprising at least one conditioning unit (8) connected to an outlet (7) or an intermediate stage of the pump for removing contaminations in at least a part of the well fluid; and a fluid connection (14) between the mechanical seal (5) and the conditioning unit (8) adapted to lead conditioned well fluid from the conditioning unit (8) to the mechanical seal (5).
3. The pump unit according to claim 1 or 2, wherein the motor is a high speed motor with a direct drive of the pump.
4. The pump unit according to claim 2, wherein the conditioning unit (8) comprises at least one hydrocyclone with particle removing features; a fluid connection (16) between the at least one hydro cyclone and the inlet side of the pump, for leading the removed particles to the inlet side of the pump for disposal.
5. A method for preventing ingress of unconditioned well fluid in at least one mechanical seal (5) of a pump for pumping unconditioned well fluid comprising: leading a well fluid from a well to a pump; pumping the well fluid with the pump; leading a fraction of the well fluid from an outlet (7) or an intermediate step of the pump to a conditioning unit (8); conditioning the well fluid with the conditioning unit to remove contaminations in the well fluid; and leading the well fluid from the conditioning unit (8) to the at least one mechanical seal (5) to displace contaminated well fluid from the seal (5).
PCT/NO2006/000430 2005-12-22 2006-11-24 Pump unit and method for pumping a well fluid WO2007073195A1 (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NO20056117 2005-12-22
NO20056117A NO324811B1 (en) 2005-12-22 2005-12-22 underwater Pump

Publications (1)

Publication Number Publication Date
WO2007073195A1 true WO2007073195A1 (en) 2007-06-28

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Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2479437A3 (en) * 2010-12-30 2014-09-10 Nuovo Pignone S.p.A. Motor compressor system and method
US9126986B2 (en) 2011-12-28 2015-09-08 Janssen Sciences Ireland Uc Hetero-bicyclic derivatives as HCV inhibitors

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5207291A (en) * 1991-04-11 1993-05-04 Nuovopignone-Industrie Meccaniche E Fonderia S.P.A. Barrier system for the lubricating oil for the bearings of a centrifugal compressor with labyrinth seals installed in a confined environment
US5382141A (en) * 1991-02-08 1995-01-17 Kvaener Rosenberg A.S. Kvaerner Subsea Contracting Compressor system and method of operation
US5765998A (en) * 1995-06-22 1998-06-16 Mannesmann Aktiengesellschaft Process and apparatus for ensuring the operability of gas seals in turbocompressors
WO2003035225A1 (en) * 2001-10-24 2003-05-01 Kvaerner Eureka As Method for operating a submarine, rotating device and an apparatus for said device
EP1420167A2 (en) * 2002-11-13 2004-05-19 Nuovo Pignone Holding S.P.A. Device for circulating sealing gas for mechanical dry seals of a centrifugal compressor
NO20054179L (en) * 2003-07-02 2005-01-03 Kvaerner Oilfield Prod As Device for regulating the pressure in the underwater compressor module

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5382141A (en) * 1991-02-08 1995-01-17 Kvaener Rosenberg A.S. Kvaerner Subsea Contracting Compressor system and method of operation
US5207291A (en) * 1991-04-11 1993-05-04 Nuovopignone-Industrie Meccaniche E Fonderia S.P.A. Barrier system for the lubricating oil for the bearings of a centrifugal compressor with labyrinth seals installed in a confined environment
US5765998A (en) * 1995-06-22 1998-06-16 Mannesmann Aktiengesellschaft Process and apparatus for ensuring the operability of gas seals in turbocompressors
WO2003035225A1 (en) * 2001-10-24 2003-05-01 Kvaerner Eureka As Method for operating a submarine, rotating device and an apparatus for said device
EP1420167A2 (en) * 2002-11-13 2004-05-19 Nuovo Pignone Holding S.P.A. Device for circulating sealing gas for mechanical dry seals of a centrifugal compressor
NO20054179L (en) * 2003-07-02 2005-01-03 Kvaerner Oilfield Prod As Device for regulating the pressure in the underwater compressor module

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2479437A3 (en) * 2010-12-30 2014-09-10 Nuovo Pignone S.p.A. Motor compressor system and method
US9126986B2 (en) 2011-12-28 2015-09-08 Janssen Sciences Ireland Uc Hetero-bicyclic derivatives as HCV inhibitors

Also Published As

Publication number Publication date
NO20056117L (en) 2007-06-25
NO324811B1 (en) 2007-12-10

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