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US20150021235A1 - Method and system for providing fuel gas to a topside facility - Google Patents

Method and system for providing fuel gas to a topside facility Download PDF

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Publication number
US20150021235A1
US20150021235A1 US14/380,720 US201314380720A US2015021235A1 US 20150021235 A1 US20150021235 A1 US 20150021235A1 US 201314380720 A US201314380720 A US 201314380720A US 2015021235 A1 US2015021235 A1 US 2015021235A1
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US
United States
Prior art keywords
gas
crude oil
subsea
stream
outlet
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
US14/380,720
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English (en)
Inventor
Steinar Eriksen
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.)
TechnipFMC Norge 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
Publication of US20150021235A1 publication Critical patent/US20150021235A1/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
    • 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 an offshore processing method, especially the present invention relates to an offshore processing method for providing fuel for an offshore processing system which can be combined with a method for stabilization of oil for tanker transport.
  • Stabilization of crude oil for tanker transport comprises controlled degasification of the crude oil.
  • the offshore top side processing equipment requires power for driving mechanical equipment and for providing heat.
  • the power can be provided through electrical cables connected to onshore power plants or be generated offshore through combustion of fuel or a combination thereof.
  • WO 03/033872 relates to an installation arranged on the sea bed for the separation of fluids, comprising at least one separator that is connected to one or more wells, each via an associated well head or similar, and a pipeline.
  • the components separated, oil, gas, water or combinations of these substances, are fed fully or partially from the installation to a platform, vessel etc. on the surface via collecting pipelines onto shore, or are re-injected into the formation beneath the sea bed.
  • Each separator consist of a long pipe (pipe separator) that may form a major or minor part of the transport pipeline from the well and has a diameter that is mainly equal to or slightly larger that the diameter of the transport pipeline.
  • An aim of the present invention is to provide a method for providing fuel to a topside platform from a subsea well which utilizes equipment mainly provided for other purposes.
  • Another aim is to provide a method for stabilisation of oil for tanker transport.
  • the present invention provides a method for providing fuel gas to a top-side processing system of a sub-sea well stream, where the method comprises separating the sub-sea well stream in a sub-sea arranged three phase separator obtaining a crude oil stream, and a crude natural gas stream, separating acid gasses and/or water from the crude natural gas, pressurizing the gas stream sub-sea, adding at least part of the pressurized gas to the crude oil stream subsea, transporting the added gas together with the oil to the topside, separating the gas from the oil in a first stabilization stage and providing the separated gas as fuel gas to a fuel gas system.
  • the method further comprises removing water from the crude oil stream subsea to obtain dry crude oil, transporting the dry crude oil to the topside processing system.
  • Removing water from the crude oil stream subsea may in another aspect comprise passing the crude oil trough a subsea arranged electrostatic coalescer.
  • the crude oil stream is stabilized for tanker transport in the top-side processing system through removal of dissolved gas.
  • the first stabilization stage operates at a gas pressure equal to a pressure required for the topside fuel gas system.
  • the crude oil is stabilized in the first stage and in a second stage with interstage heating.
  • the step of separating acid gasses and/or water from the crude natural gas is performed subsea.
  • the present invention provides a subside well, topside fuel gas providing system comprising a sub-sea arranged three phase separator with a well stream inlet and at least a crude natural gas outlet and a crude oil outlet, a riser with a subsea riser inlet in fluid communication with the crude oil outlet and in fluid communication with the crude natural gas outlet and a topside riser outlet in fluid communication with a topside arranged stabilization unit comprising a stabilized crude oil outlet and a fuel gas outlet.
  • system further comprises a subsea gas treatment system down stream the three phase separator with an inlet in fluid communication with the crude natural gas outlet and with a treated gas outlet in fluid communication with the riser.
  • system comprises a sub-sea arranged water removal unit arranged downstream the three phase separator with a crude oil inlet in fluid communication with the crude oil outlet, a dry crude oil outlet in fluid communication with the riser and a water outlet.
  • water removal unit comprises an electrostatic coalescer.
  • the fuel gas outlet is in fluid communication with a fuel gas inlet to a topside arranged power generating unit.
  • system further comprises a subsea natural gas compressor with an inlet in fluid communication with the natural gas outlet and a pressurized gas outlet in communication with the riser.
  • topside refers to a position in proximity of the sea level.
  • part of the equipment may be installed above or below the sea level but with in or on the floating vessel or platform.
  • topside should be interpreted to refer to any position on the platform above sea level.
  • FIG. 1 schematically illustrates a first embodiment of the present invention.
  • FIG. 2 schematically illustrates a second embodiment of the present invention.
  • FIG. 3 schematically illustrates a third embodiment of the present invention.
  • FIG. 4 illustrates the process scheme of a fourth embodiment of the present invention.
  • FIG. 1 illustrates a first embodiment of the present invention.
  • a well stream 1 is fed to a subsea three-phase separator 2 , to obtain a water stream 19 , a crude oil stream 13 and a gas stream 3 .
  • the water stream 19 is transferred to a produced water treatment system 4 .
  • the gas stream 3 is past through a heat exchanger 8 to obtain a cooled gas 5 .
  • the cooling results in condensation of higher hydrocarbons which are separated in separator 10 .
  • the liquid stream 7 is via pump 12 and pipe 9 mixed with the main oil stream from the separator 2 .
  • the gas 11 leaving over the top of the separator 10 is subject to a treatment system 22 conditioning the gas for pipeline transport.
  • the conditioned gas 51 is pressurized in subsea compressor 52 to obtain pressurised gas 53 .
  • the oil stream 81 comprising the main crude oil stream 13 and the condensed oil 9 is transported via a pump 80 and a pipeline 83 .
  • a part 57 of the pressurized gas is added to the oil before the oil is transferred to top side via line 85 .
  • the rest of the gas is transferred via heat exchanger 54 and pipeline 55 to shore.
  • the mixture of gas and oil is transported to a topside installation 90 in riser 85 .
  • the oil is dehydrated and gas initially present as well as the added gas is removed in a first stabilization step 84 .
  • Stream 87 is stabilized oil, depending on the restrictions for tanker transport additional oil treatment may if necessary be performed on the topside installation.
  • Stream 89 comprises the added gas stream 57 as well as any additional gas released from the crude oil. This stream 89 is fed as fuel gas to a topside gas fuel power providing system 86 .
  • FIG. 2 illustrates an alternative embodiment of the present invention, wherein the at least partly stabilized crude oil 87 is returned from the topside installation to subside, and transported to shore together with the compressed gas 55 as stream 65 via a subsea pipeline.
  • the crude oil is transferred to the topside installation to be dried.
  • For pipeline transport together with the crude gas both the gas and the oil need to be dried to avoid hydrate formation.
  • FIG. 3 illustrates a further embodiment of the present invention.
  • the initial oil treatment system 6 is arranged subsea.
  • the crude oil is dehydration for instance by use of electrostatic coalescers. Separated water is past as stream 15 to the produced water treatment system 4 .
  • the dehydrated oil 81 is via pump 80 transferred to the topside installation 90 together with treated gas 57 .
  • the stabilization system 84 comprises one or more stabilization steps where gas is flashed of from the crude oil.
  • the first step is preferably performed at a pressure equal to the pressure required by the fuel gas system 86 so that it is not required to compressed the fuel gas 89 before feeding it to the fuel gas system 86 .
  • the fuel gas is a combination of the added gas 57 and the gas present in the crude oil prior to stabilization.
  • Additional stabilization steps may be included within unit 84 to allow for removal of additional gas to secure quality applicable for tanker transport. These additional steps will be performed at a lower pressure than the pressure of the fuel gas. If significant amounts of gas are released at a lower pressure, then the treatment system may also comprise a compressor to increase the pressure of the removed gas to the pressure required by the fuel system. Alternatively, if there are two fuel gas systems topside; 1) for feeding the generator turbine (high pressure) and 2) one for feeding a direct fired heater to provide heating medium, then the gas released at lower pressure is fed to the fuel system for the direct fired heater. Alternatively if the pressure of the removed gas obtained in the first step is larger than the pressure needed for the fuel system. The two gas streams, from the first step with to high pressure and from the additional step with to low pressure may be combined before they are fed to the fuel gas system with the correct pressure.
  • FIG. 4 illustrated an embodiment of the present invention in further detail.
  • the well fluid 1 enters a phase separator 2 , where the gas stream 3 is separated from the liquid.
  • a water stream 19 is passed to a produced water treatment system 4 , and the oil stream 13 is past to an oil treatment system 6 .
  • the gas 3 is initially cooled by cooler 8 to obtain cooled gas 5 .
  • the cooling results in condensation of higher hydrocarbons which are separated in separator 10 .
  • the liquid stream 7 is via pump 12 and pipe 9 mixed with the main oil stream from the separator 2 .
  • the gas 11 leaving over the top of the separator 10 is subject to a gas treatment system. In FIGS. 1-3 this was referred to as system 22 whereas here one embodiment of this system is disclosed in detail.
  • the crude gas stream 11 comprising a compound to be removed such as CO 2 and/or other acid gasses is fed to a contactor system 14 , 16 arranged subsea.
  • the contactor system is a 2 stage process with an initial direct contactor 14 and a traditional contactor column 16 .
  • the present invention is not limited to this embodiment but any contactor system applicable for subsea arrangement may be employed.
  • the gas stream is brought in contact with a treatment solution stream fed trough pipe 23 .
  • the obtained gas treatment solution mixture proceeds as stream 17 into the contactor column 16 .
  • Lean treatment solution is provided to the column from pipe 21 .
  • the treatment solution for the direct contactor is obtained from the column 16 at a level above the gas inlet, however the present invention is not limited to this solution as lean treatment solution could also be fed to the direct contactor as well as the column.
  • the treatment solution comprises one or more species that at least with some selectivity absorb the compound to be removed from the crude gas stream.
  • a species and solvent/diluent applicable for forming an effective treatment solution can be selected by the user depending on the compound to be removed and the prevailing conditions within the system.
  • the compound to be removed is absorbed in the solution.
  • the crude gas accordingly at least partly depleted from the compound to be removed leaves over the top of the column trough pipeline 31 .
  • the main crude gas stream accordingly stays subsea during the treatment process.
  • the rich treatment solution leaves the contactor 16 trough the bottom outlet pipeline 25 .
  • a pump 18 is provided to force the rich treatment solution 25 to proceed up through the riser or pipeline 27 .
  • a regeneration system 20 is installed on a topside facility 90 . The system receives the rich solution from pipeline 27 , desorbes and separates the absorbed compound there from and obtains a depleted treatment solution which is send back to the subsea contactor system trough pipeline/riser 21 . The desorbed compound leaves the regeneration unit 20 as stream 29 . If the compound is CO 2 the stream 29 may be treated and compressed in unit 60 and from there transported via pipeline 61 to a subsea injection well (not shown).
  • the obtained treated gas 31 enters a second system for removal of a second compound, such as water.
  • the system comprises a direct contactor 34 , where the gas is brought in contact with a treatment solution stream 43 .
  • the obtained mixture is fed to a contactor column 36 .
  • the rich treatment solution leaves via the bottom as stream 45 , via pump 38 and is transported via pipeline 47 to a top side installation 90 and a regeneration unit 40 .
  • the compound absorbed in the rich treatment solution is released resulting in a compound stream 49 and a lean treatment solution 41 being returned to the subsea contactor 36 .
  • the stream 49 is steam that can be released to the atmosphere.
  • the treated gas stream 51 leaving over the top of 36 can be compressed in compressor 52 and the temperature of the compressed gas 53 controlled by heat exchanger 54 .
  • heat exchanger 54 the temperature of the compressed gas 53 controlled by heat exchanger 54 .

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (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)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Separation By Low-Temperature Treatments (AREA)
US14/380,720 2012-02-23 2013-02-21 Method and system for providing fuel gas to a topside facility Abandoned US20150021235A1 (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
NO20120188A NO20120188A1 (no) 2012-02-23 2012-02-23 Fremgangsmate og system for a tilveiebringe brenselgass til en toppside-fasilitet
NO20120188 2012-02-23
PCT/EP2013/053415 WO2013124338A2 (en) 2012-02-23 2013-02-21 Method and system for providing fuel gas to a topside facility

Publications (1)

Publication Number Publication Date
US20150021235A1 true US20150021235A1 (en) 2015-01-22

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US14/380,720 Abandoned US20150021235A1 (en) 2012-02-23 2013-02-21 Method and system for providing fuel gas to a topside facility

Country Status (3)

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US (1) US20150021235A1 (no)
NO (1) NO20120188A1 (no)
WO (1) WO2013124338A2 (no)

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20150013539A1 (en) * 2012-02-23 2015-01-15 Fmc Kongsberg Subsea As Offshore processing method and system
WO2018009450A1 (en) * 2016-07-07 2018-01-11 Hellervik Oilfield Technologies LLC Oil conditioning unit and process
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
WO2020231271A1 (en) * 2019-05-13 2020-11-19 Equinor Energy As A method and system for preparing a fluid produced at an offshore production facility for transportation
WO2024064250A1 (en) * 2022-09-21 2024-03-28 Air Liquide Advance Technologies U.S. Llc Improved system and method for recovery of fuel gas from crude oil purification

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR102203738B1 (ko) * 2013-12-26 2021-01-15 대우조선해양 주식회사 바이패스부를 구비한 탑사이드 분리기 시스템

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
NO312138B1 (no) * 2000-05-04 2002-03-25 Kongsberg Offshore As Fremgangsmåte og sjöbasert installasjon for håndtering og behandling av flerfraksjonshydrokarboner til sjös
NO20010589A (no) * 2001-02-05 2002-08-05 Navion Asa Fremgangsmåte og sjøbasert anlegg for behandling og håndtering av hydrokarboner
NO316837B1 (no) * 2001-10-17 2004-05-24 Norsk Hydro As Anordning for separasjon av fluider
GB2404684B (en) * 2002-04-08 2005-10-26 Offshore Systems Inc Subsea well production facility

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20150013539A1 (en) * 2012-02-23 2015-01-15 Fmc Kongsberg Subsea As Offshore processing method and system
US9638019B2 (en) * 2012-02-23 2017-05-02 Fmc Kongsberg Subsea As Offshore processing method and system
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
WO2018009450A1 (en) * 2016-07-07 2018-01-11 Hellervik Oilfield Technologies LLC Oil conditioning unit and process
US10287509B2 (en) 2016-07-07 2019-05-14 Hellervik Oilfield Technologies LLC Oil conditioning unit and process
WO2020231271A1 (en) * 2019-05-13 2020-11-19 Equinor Energy As A method and system for preparing a fluid produced at an offshore production facility for transportation
WO2024064250A1 (en) * 2022-09-21 2024-03-28 Air Liquide Advance Technologies U.S. Llc Improved system and method for recovery of fuel gas from crude oil purification
US12344806B2 (en) 2022-09-21 2025-07-01 Air Liquide Advanced Technologies U.S. Llc System and method for recovery of fuel gas from crude oil purification

Also Published As

Publication number Publication date
WO2013124338A2 (en) 2013-08-29
NO20120188A1 (no) 2013-08-26
WO2013124338A3 (en) 2014-04-10

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