WO2014154470A2 - Separation system using heat of compression - Google Patents
Separation system using heat of compression Download PDFInfo
- Publication number
- WO2014154470A2 WO2014154470A2 PCT/EP2014/054459 EP2014054459W WO2014154470A2 WO 2014154470 A2 WO2014154470 A2 WO 2014154470A2 EP 2014054459 W EP2014054459 W EP 2014054459W WO 2014154470 A2 WO2014154470 A2 WO 2014154470A2
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- separator
- fluid
- compression unit
- subsea system
- heat exchanger
- Prior art date
Links
- 230000006835 compression Effects 0.000 title claims abstract description 52
- 238000007906 compression Methods 0.000 title claims abstract description 52
- 238000000926 separation method Methods 0.000 title claims description 30
- 239000012530 fluid Substances 0.000 claims abstract description 57
- 238000000034 method Methods 0.000 claims description 28
- 238000011144 upstream manufacturing Methods 0.000 claims description 20
- 238000001556 precipitation Methods 0.000 claims description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 16
- 239000012071 phase Substances 0.000 description 13
- 238000001816 cooling Methods 0.000 description 3
- 238000011143 downstream manufacturing Methods 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 238000005086 pumping Methods 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 238000005260 corrosion Methods 0.000 description 2
- 230000007797 corrosion Effects 0.000 description 2
- 238000000151 deposition Methods 0.000 description 2
- 238000010438 heat treatment Methods 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 239000008346 aqueous phase Substances 0.000 description 1
- 239000012809 cooling fluid Substances 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 230000008021 deposition Effects 0.000 description 1
- 238000005485 electric heating Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000013535 sea water Substances 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
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
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/36—Underwater separating arrangements
-
- 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
Definitions
- the present invention relates to a subsea system, and especially to a subsea system where at least some of the heat in the fluid flow as a result of compression of the fluid flow, is used to heat a 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 a case with 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 increasing the pressure in the fluid and at the same time increase 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, providing heat transfer from at least a part of the fluid in the compression unit outlet line with the separator inlet line.
- 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, when such processing is aided by the reduced temperature.
- a possible embodiment is to provide a heat exchanger for heat transfer between the compression unit outlet line fluid and the separator inlet line fluid.
- 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.
- bleed off a part of the compressed process fluid relieve the pressure and guide it directly into the process stream to heat this.
- the bleed off may take place after or in a mixer to make sure 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 with 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 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.
- one may have 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 in the process flow, to increase the temperature with mixing.
- Another possibility is to have this phase not flowing through the heat exchanger in a bypass line and 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 process equipment.
- Any cooler between or after 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 sketch of some possible configurations of the invention
- Fig. 2 is a possible embodiment where the invention is used
- Fig. 1 is a sketch of possible principles of the invention, only elements relevant for the understanding of the invention is shown, as there may be many additional elements in the system.
- a subsea system comprising a separator 1 with an inlet line 2 and an outlet line 3.
- the inlet line is connected to an upstream source which may 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.
- a compression unit 4 in the subsea system, with an inlet line 5 an and 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 from 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 7 unit may be a heat exchanger or it may be 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 would be cooled while heating the fluid in the inlet line 2 towards 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 would separate the outlet fluid in the outlet line 6 into two streams and possibly guide one of these through the heat exchanger 7 and another in a bypass line 9. These may downstream be connected again or lead to different equipment subsea.
- Another possibility is to have the unit 8 as a splitter, splitting the oulet line 6 fluid into two or more streams, whereof one or several are guided through a heat exchanger 7.
- Another possibility is to have the unit 8 split of a part of the fluid in the outlet line 6 and then introduce this into a mixer 7 after the pressure is bled off to mix with the fluid in the inlet line of the separator 1.
- inlet line 2 to the separator may be divided with one part through a heat exchanger and one part as a bypass.
- Fig. 2 shows one possible embodiment of implementing 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 in a first and second separator.
- a first compression unit 12 downstream of the second separator and there may possibly also be arranged a compression unit 1 1 upstream of at least one of the separators, in the figures indicated with a
- compression unit 1 1 upstream of the first separator.
- the fluid exiting the second separator is pressurized in one compression unit 12 and is then lead through a first heat exchanger positioned between the first and second separator and then further through a possible heat exchanger upstream of the first stage separation.
- the heat exchanger upstream of the first separation stage is positioned between the separator and a possible upstream compression unit .
- Produced water from the first and second separation stages are guided into a produced water treatment unit. Oily reject 15 may from this treatment unit be introduced into the flow upstream of the first or second separation stage.
- the water to be reinjected is lead out from the treatment unit to a water reinjection pump 13. Part of the flow from the pump may be reintroduced 16 in to the treatment unit.
- compression or multiphase pumping 1 1 , 12 is located at different steps in the process, in this case upstream of the first processing step and after the secondary separation step.
- the first compression unit 1 1 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 reducing the size and weight of the separator vessels.
- the injection water pump 13 size 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, there is water pressure 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, since water is removed from stream 14, the gas volume fraction into pump or compressor 12 is maximized because water is removed, thus increasing the temperature out of 12, gas is included in the hot side of the heat exchange, 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 (out of last step pump) and lead it either as separate streams of gas and liquid, or as split multiphase streams, to two or more heat exchangers.
- FIG. 1 Another variety of this arrangement, also not shown in Fig 1 or Fig 2, is to have 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 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 may be recombined with the process stream up- or downstream of each separation stage.
Landscapes
- 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)
- Compressor (AREA)
- Waste-Gas Treatment And Other Accessory Devices For Furnaces (AREA)
- Separation By Low-Temperature Treatments (AREA)
- Apparatus For Radiation Diagnosis (AREA)
- Surgical Instruments (AREA)
- Structures Of Non-Positive Displacement Pumps (AREA)
Abstract
Description
Claims
Priority Applications (5)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
BR112015024673A BR112015024673A2 (en) | 2013-03-26 | 2014-03-07 | separation system using compression heat. |
SG11201507961UA SG11201507961UA (en) | 2013-03-26 | 2014-03-07 | Separation system using heat of compression |
US14/780,512 US20160047217A1 (en) | 2013-03-26 | 2014-03-07 | Separation system using heat of compression |
AU2014243330A AU2014243330B2 (en) | 2013-03-26 | 2014-03-07 | Separation system using heat of compression |
EP14709609.3A EP2978929B1 (en) | 2013-03-26 | 2014-03-07 | Separation system using heat of compression |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
NO20130430 | 2013-03-26 | ||
NO20130430A NO337623B1 (en) | 2013-03-26 | 2013-03-26 | Separation system that uses heat in compression |
Publications (2)
Publication Number | Publication Date |
---|---|
WO2014154470A2 true WO2014154470A2 (en) | 2014-10-02 |
WO2014154470A3 WO2014154470A3 (en) | 2015-03-12 |
Family
ID=50272594
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/EP2014/054459 WO2014154470A2 (en) | 2013-03-26 | 2014-03-07 | Separation system using heat of compression |
Country Status (7)
Country | Link |
---|---|
US (1) | US20160047217A1 (en) |
EP (1) | EP2978929B1 (en) |
AU (1) | AU2014243330B2 (en) |
BR (1) | BR112015024673A2 (en) |
NO (1) | NO337623B1 (en) |
SG (1) | SG11201507961UA (en) |
WO (1) | WO2014154470A2 (en) |
Families Citing this family (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
AU2015372685B2 (en) * | 2014-12-29 | 2020-09-17 | Aker Carbon Capture Norway As | Subsea fluid processing system |
US20220381128A1 (en) * | 2021-05-27 | 2022-12-01 | J. Ray McDermott | Compression heat integrated high efficiency offshore process platform unit |
Citations (4)
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 |
US20070029091A1 (en) * | 2003-09-12 | 2007-02-08 | Stinessen Kjell O | Subsea compression system and method |
US20100006291A1 (en) * | 2006-07-07 | 2010-01-14 | Edwin Poorte | Method of cooling a multiphase well effluent stream |
US20100155970A1 (en) * | 2006-07-07 | 2010-06-24 | Edwin Poorte | Method of cooling a multiphase well effluent stream |
Family Cites Families (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB0618001D0 (en) * | 2006-09-13 | 2006-10-18 | Des Enhanced Recovery Ltd | Method |
-
2013
- 2013-03-26 NO NO20130430A patent/NO337623B1/en not_active IP Right Cessation
-
2014
- 2014-03-07 SG SG11201507961UA patent/SG11201507961UA/en unknown
- 2014-03-07 AU AU2014243330A patent/AU2014243330B2/en not_active Ceased
- 2014-03-07 WO PCT/EP2014/054459 patent/WO2014154470A2/en active Application Filing
- 2014-03-07 US US14/780,512 patent/US20160047217A1/en not_active Abandoned
- 2014-03-07 BR BR112015024673A patent/BR112015024673A2/en active Search and Examination
- 2014-03-07 EP EP14709609.3A patent/EP2978929B1/en not_active Not-in-force
Patent Citations (4)
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 |
US20070029091A1 (en) * | 2003-09-12 | 2007-02-08 | Stinessen Kjell O | Subsea compression system and method |
US20100006291A1 (en) * | 2006-07-07 | 2010-01-14 | Edwin Poorte | Method of cooling a multiphase well effluent stream |
US20100155970A1 (en) * | 2006-07-07 | 2010-06-24 | Edwin Poorte | Method of cooling a multiphase well effluent stream |
Also Published As
Publication number | Publication date |
---|---|
EP2978929A2 (en) | 2016-02-03 |
BR112015024673A2 (en) | 2017-09-26 |
AU2014243330A1 (en) | 2015-09-24 |
NO20130430A1 (en) | 2014-09-29 |
NO337623B1 (en) | 2016-05-09 |
US20160047217A1 (en) | 2016-02-18 |
SG11201507961UA (en) | 2015-10-29 |
EP2978929B1 (en) | 2017-01-04 |
AU2014243330B2 (en) | 2017-05-25 |
WO2014154470A3 (en) | 2015-03-12 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US7819950B2 (en) | Subsea compression system and method | |
WO2010037970A3 (en) | Cooling circuit for the thermal regulation of an engine independent from other consumers | |
WO2007067059A1 (en) | All electric subsea boosting system | |
JP2009191725A (en) | Waste heat utilization device | |
AU2015284617C1 (en) | Fluid processing system, heat exchange sub-system, and an associated method thereof | |
US10827649B2 (en) | Cooling fluids in opposite directions across a device | |
EP2978929B1 (en) | Separation system using heat of compression | |
US9512700B2 (en) | Subsea fluid processing system and an associated method thereof | |
RU119389U1 (en) | INSTALLATION FOR PREPARATION OF GAS OIL AND GAS-CONDENSATE DEPOSITS FOR TRANSPORT | |
US20230332521A1 (en) | Reduced parasitic lube system | |
CN105065900A (en) | Light hydrocarbon recovery technology for LNG receiving terminal | |
WO2013135600A2 (en) | Subsea flow splitting arrangement | |
CA2629384C (en) | Flow divider and separation system | |
US10962002B2 (en) | Multi-phase pump with cooled liquid reservoir | |
US20180056231A1 (en) | Variable side cooling for acid gas removal | |
AU2013274971B2 (en) | Using wellstream heat exchanger for flow assurance | |
JP2014145520A (en) | Drain recovery and recycle system | |
RU2527922C1 (en) | Installation for hydrocarbon gas preparation | |
WO2016088159A1 (en) | Equipment safety management device, equipment safety management method, and natural gas liquefaction device | |
US20190041130A1 (en) | Method and device for separating air by cryogenic distillation | |
AU2013274973B2 (en) | Heat exchange from compressed gas | |
GB2433759A (en) | Subsea compression system and method | |
KR20180089762A (en) | MEG Recovery Apparatus using Pre-flash Drum | |
WO2015002054A1 (en) | Separation method and separation device | |
WO2015097531A1 (en) | A subsea fluid processing system |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 14709609 Country of ref document: EP Kind code of ref document: A2 |
|
ENP | Entry into the national phase |
Ref document number: 2014243330 Country of ref document: AU Date of ref document: 20140307 Kind code of ref document: A |
|
WWE | Wipo information: entry into national phase |
Ref document number: 14780512 Country of ref document: US |
|
REEP | Request for entry into the european phase |
Ref document number: 2014709609 Country of ref document: EP |
|
WWE | Wipo information: entry into national phase |
Ref document number: 2014709609 Country of ref document: EP |
|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 14709609 Country of ref document: EP Kind code of ref document: A2 |
|
REG | Reference to national code |
Ref country code: BR Ref legal event code: B01A Ref document number: 112015024673 Country of ref document: BR |
|
ENP | Entry into the national phase |
Ref document number: 112015024673 Country of ref document: BR Kind code of ref document: A2 Effective date: 20150925 |