US20160047217A1 - Separation system using heat of compression - Google Patents

Separation system using heat of compression Download PDF

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Publication number
US20160047217A1
US20160047217A1 US14/780,512 US201414780512A US2016047217A1 US 20160047217 A1 US20160047217 A1 US 20160047217A1 US 201414780512 A US201414780512 A US 201414780512A US 2016047217 A1 US2016047217 A1 US 2016047217A1
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US
United States
Prior art keywords
separator
fluid
compression unit
subsea system
heat exchanger
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
US14/780,512
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English (en)
Inventor
Sven Haagensen Høy
Andreas Hannisdal
Henrik Bjartnes
Haakon Ellingsen
Jostein Kolbu
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.)
FMC Kongsberg Subsea AS
Original Assignee
FMC Kongsberg Subsea 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 FMC Kongsberg Subsea AS filed Critical FMC Kongsberg Subsea AS
Assigned to FMC KONGSBERG SUBSEA AS reassignment FMC KONGSBERG SUBSEA AS ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: HANNISDAL, Andreas, BJARTNES, Henrik, ELLINGSEN, Haakon, HØY, SVEN HAAGENSEN, KOLBU, Jostein
Publication of US20160047217A1 publication Critical patent/US20160047217A1/en
Abandoned legal-status Critical Current

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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
    • E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • E21B36/006—Combined heating and pumping means
    • 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 system, and especially to a subsea system wherein at least some of the heat in the fluid flow resulting compression of the fluid flow is used to heat the fluid flow before it enters a separation stage.
  • This subsea system is especially relevant for gas rich fluid flows or multiphase fluid flows.
  • the present invention provides a device and method for providing a separation system with increased capacity in the case of a gas rich fluid stream or a multiphase fluid stream.
  • a subsea system comprising a separator with a fluid inlet line and at least one outlet line.
  • the subsea system also comprises a compression unit for a gas rich fluid flow with an inlet line and an outlet line.
  • the compression unit may be a pump, a multiphase pump, a compressor or other kind of element for increasing the pressure in the fluid and at the same time increasing the temperature in the fluid due to the compression.
  • the system is further provided with a connection between the outlet line from the compression unit and the inlet line of the separator to provide heat transfer from at least a part of the fluid in the compression unit outlet line to the separator inlet line.
  • This provides a separation system that uses heat from gas compression or gas-liquid compression (also denoted multiphase pumping or wet gas compression) to increase the temperature in the process flow entering the separation station, so that the viscosity of the process flow is reduced and the separation efficiency of all involved phases therefore can be increased.
  • gas compression or gas-liquid compression also denoted multiphase pumping or wet gas compression
  • the process fluids entering the separation station which are heated by the compressed fluids will have a reduced propensity to deposit wax or other substances onto the internal surfaces of the separators and any process equipment for produced water treatment.
  • the temperature increase associated with the compression of fluids will be reduced by means of heat transfer thus enabling further downstream processing of separated or non-separated process phases, where such processing is aided by the reduced temperature.
  • a possible embodiment provides a heat exchanger for heat transfer between the fluid in the compression unit outlet line and the fluid in the separator inlet line.
  • Another possibility is to take a part of the flow at the outlet from the compression unit and mix this with the well stream at the inlet of the separator.
  • This part of the flow may be a part of a multiphase flow or a part of a phase divided flow.
  • the temperature increase in the process fluid can be achieved by recirculation of and commingling with process fluid that has been compressed in a pump or compressor, thus avoiding the use of a heat exchanger.
  • a part of the compressed process fluid can be bled off, its pressure relieved, and then it can be guided directly into the process stream to be heated.
  • the bleed off may take place after or in a mixer to ensure an even distribution of phases in the two or more flows.
  • the compression unit in the form of a multiphase pump or compressor may, according to one embodiment, be placed after, or in other words, downstream of the separation station.
  • the separation station may comprise several stages and sub-processes.
  • the multiphase pump or compressor can be placed between the separation stages or between process parts, according to the requirements of these stages and process parts.
  • Any gas in the process fluid can be separated from other phases after the pump or compressor, according to the requirements of the stages and process parts.
  • a heat exchanger at the inlet of the separator with only one phase in the flow through the heat exchanger.
  • Another possibility is to have one phase through the heat exchanger and at least a part of the flow not flowing through the heat exchanger bled down in pressure and introduced into the process flow to increase the temperature with mixing.
  • Another possibility is to have this phase bypass the heat exchanger in a bypass line and be remixed with the split phase downstream of the heat exchanger.
  • Any gas in the process fluid can be intermediately separated from the other phases upstream of the compression unit.
  • the pump or compressor may alternatively be placed upstream of the separation station, thus improving separation efficiency through a temperature increase, and/or preventing wax or other temperature-influenced deposition on or inside the process equipment.
  • Any cooler between or after the separation stages or other process parts can be used to reduce the process fluid temperature, according to the requirements of equipment downstream of the cooler.
  • FIG. 1 is a schematic representation of one embodiment the invention
  • FIG. 2 is a schematic representation of another embodiment of the invention.
  • FIG. 3 is a schematic representation of yet another embodiment of he invention.
  • FIG. 1 is a representation of a first embodiment of the invention, only the elements relevant for the understanding of the invention being shown, as many additional elements in the system may exist.
  • the subsea system shown in FIG. 1 comprises a separator 1 with an inlet line 2 and an outlet line 3 .
  • the inlet line 2 is connected to an upstream source which may, e.g., be the wellhead or another upstream subsea unit, as for instance a separator.
  • There would normally be an additional outlet line from the separator 1 which is not shown in the drawings as it is not directly relevant for the invention.
  • the subsea system also comprises a compression unit 4 with an inlet line 5 and an outlet line 6 .
  • the compression unit may be a compressor or a multiphase pump.
  • the inlet line 5 of the compression unit may as indicated with the dotted line 10 be connected directly with the outlet line 3 of the separator 1 . Another possibility is to have the inlet line 5 be connected to another fluid source.
  • the outlet line 6 is guided into a heat transfer unit 7 which is connected to the inlet line 2 of the separator 1 .
  • This heat transfer unit 7 may be a heat exchanger or a mixer.
  • the fluid in the outlet line 6 of the compressor 4 may in one embodiment be guided through the heat exchanger 7 . Exiting this heat exchanger, the fluid is cooled while heating the fluid in the inlet line 2 of the separator 1 .
  • a unit 8 in the form of a separator in the outlet line 6 downstream of the compression unit 4 .
  • This separator 8 would separate the outlet fluid in the outlet line 6 into two streams and possibly guide one of these streams through the heat exchanger 7 and the other stream into a bypass line 9 . These streams may be connected again downstream or lead to different equipment subsea.
  • Another possibility is to have the unit 8 be a splitter, splitting the fluid in the outlet line 6 into two or more streams, whereof one or several are guided through the heat exchanger 7 .
  • Another possibility is to have the unit 8 split off a part of the fluid in the outlet line 6 and then introduce this fluid into a mixer 7 after the pressure is bled off to mix with the fluid in the inlet line 2 of the separator 1 .
  • the inlet line 2 to the separator may be divided, with one part leading through a heat exchanger and another part through a bypass.
  • FIG. 2 shows another embodiment of the invention.
  • the separation process comprises a first separation stage and a second separation stage, in the form of primary and secondary separation, possibly arranged as a first separator 1 and a second separator 1 A.
  • a compression unit 12 is arranged downstream of the second separator 1 A, and a compression unit 11 may possibly be arranged upstream of at least one of the separators, such as upstream of the first separator 1 .
  • the fluid exiting the second separator 1 A is pressurized in the compression unit 12 and is then lead through a first heat exchanger 7 positioned between the first and second separators and then possibly through a second heat exchanger (not shown) positioned upstream of the first separator 1 .
  • the heat exchanger upstream of the first separator is positioned between the first separator and the optional compression unit 11 .
  • Produced water from the first and second separation stages is guided into a produced water treatment unit 20 .
  • Oily reject from this treatment unit may be lead through a line 15 and introduced into the flow upstream of the first or second separation stage.
  • the water to be re-injected into the well is lead out from the treatment unit 20 to a water reinjection pump 13 .
  • Part of the flow from the pump may be reintroduced through a line 16 back into the water treatment unit.
  • produced water from the second separation stage is lead into a reject stream treatment unit 22 , where it is treated along with the oily reject 15 from the water treatment unit 20 . If the water from the reject stream treatment unit 22 is clean enough, it is directed to the reinjection pump 13 ; otherwise, it is lead back to the produced water treatment unit 20 .
  • the compression or multiphase pumping units 11 , 12 are located at different steps in the process, in this case upstream of the first processing step and after the secondary separation step.
  • the compression unit 11 increases the stream temperature so that, e.g., the risk of wax precipitation in the oil and water treatment parts of the process is reduced.
  • the temperature increase also enhances the separation efficiency, possibly allowing for a reduction in the size and weight of the separator vessels.
  • the size of the injection water pump 13 can be reduced. Heated injection water also has a lower viscosity, which may improve water permeation into the reservoir.
  • the advantage of multiphase compression in one or several stages with heat exchange is not only that the stream leaving the subsea process for further processing or transportation is cooled. Provided that the required injection water pressure is higher than the upstream process pressure, water pressure is available for recirculation back into the produced water treatment process. Single step multiphase compression upstream of the separation process would not facilitate this.
  • the temperature of the stream 14 is maximized. Also, since water is removed from the stream 14 , the gas volume fraction into the pump or compression unit 12 is maximized, thus increasing the temperature out of the compression unit 12 .
  • gas is included in the hot side of the heat exchanger, and this gas has a relatively high heat capacity at normal processing pressures.
  • a further arrangement would be to split the gas and oil stream from the pump or compression unit 12 and lead it either as separate streams of gas and liquid, or as split multiphase streams, to two or more heat exchangers.
  • Another variety of this arrangement is to cool part of the stream from the pump or compression unit 12 with seawater, and not heat exchange this part with the process stream.
  • FIG. 2 Another variety of this arrangement, also not shown in FIG. 1 or FIG. 2 , is to provide a bypass line around each heat exchanger in order to control the fluid flow rate entering the heat exchanger and thus optimize the amount of heat transferred in each device.
  • the heat exchangers could also be arranged in parallel or in series.
  • the downstream processing may be a cooling unit for precipitation of wax out of oil, so that a pipeline will not be clogged with wax as the oil cools.
  • the heat exchange aids a downstream process like this.
  • the heat exchange could also be part of a cooling sequence to condense water from the gas phase, to obtain controlled mixing with a corrosion inhibited aqueous phase.
  • the oily reject stream 15 from the produced water treatment unit 20 may be recombined with the process stream up- or downstream of each separation stage.

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  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Physics & Mathematics (AREA)
  • Applications Or Details Of Rotary Compressors (AREA)
  • Heat-Exchange Devices With Radiators And Conduit Assemblies (AREA)
  • Structures Of Non-Positive Displacement Pumps (AREA)
  • Compressor (AREA)
  • Separation By Low-Temperature Treatments (AREA)
  • Apparatus For Radiation Diagnosis (AREA)
  • Surgical Instruments (AREA)
  • Waste-Gas Treatment And Other Accessory Devices For Furnaces (AREA)
US14/780,512 2013-03-26 2014-03-07 Separation system using heat of compression Abandoned US20160047217A1 (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
NO20130430A NO337623B1 (no) 2013-03-26 2013-03-26 Separasjonssystem som benytter varme ved kompresjon
NO20130430 2013-03-26
PCT/EP2014/054459 WO2014154470A2 (en) 2013-03-26 2014-03-07 Separation system using heat of compression

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US20160047217A1 true US20160047217A1 (en) 2016-02-18

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Application Number Title Priority Date Filing Date
US14/780,512 Abandoned US20160047217A1 (en) 2013-03-26 2014-03-07 Separation system using heat of compression

Country Status (7)

Country Link
US (1) US20160047217A1 (no)
EP (1) EP2978929B1 (no)
AU (1) AU2014243330B2 (no)
BR (1) BR112015024673A2 (no)
NO (1) NO337623B1 (no)
SG (1) SG11201507961UA (no)
WO (1) WO2014154470A2 (no)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20180002623A1 (en) * 2014-12-29 2018-01-04 Aker Solutions As Subsea fluid processing system
WO2022251018A1 (en) * 2021-05-27 2022-12-01 J. Ray Mcdermott, S.A. Compression heat integrated high efficiency offshore process platform unit

Family Cites Families (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6032737A (en) * 1998-04-07 2000-03-07 Atlantic Richfield Company Method and system for increasing oil production from an oil well producing a mixture of oil and gas
NO321304B1 (no) * 2003-09-12 2006-04-24 Kvaerner Oilfield Prod As Undervanns kompressorstasjon
NO325979B1 (no) * 2006-07-07 2008-08-25 Shell Int Research System og fremgangsmate for a kjole en flerfasebronnstrom
NO326079B1 (no) * 2006-07-07 2008-09-15 Shell Int Research Fremgangsmate for a behandle og separere en flerfaset bronnstromblanding.
GB0618001D0 (en) * 2006-09-13 2006-10-18 Des Enhanced Recovery Ltd Method

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20180002623A1 (en) * 2014-12-29 2018-01-04 Aker Solutions As Subsea fluid processing system
US10428287B2 (en) * 2014-12-29 2019-10-01 Aker Solutions As Subsea fluid processing system
WO2022251018A1 (en) * 2021-05-27 2022-12-01 J. Ray Mcdermott, S.A. Compression heat integrated high efficiency offshore process platform unit

Also Published As

Publication number Publication date
BR112015024673A2 (pt) 2017-09-26
NO20130430A1 (no) 2014-09-29
AU2014243330B2 (en) 2017-05-25
SG11201507961UA (en) 2015-10-29
WO2014154470A3 (en) 2015-03-12
EP2978929A2 (en) 2016-02-03
AU2014243330A1 (en) 2015-09-24
EP2978929B1 (en) 2017-01-04
WO2014154470A2 (en) 2014-10-02
NO337623B1 (no) 2016-05-09

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