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US20050006086A1 - Installation for the separation of fluids - Google Patents

Installation for the separation of fluids Download PDF

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Publication number
US20050006086A1
US20050006086A1 US10/492,704 US49270404A US2005006086A1 US 20050006086 A1 US20050006086 A1 US 20050006086A1 US 49270404 A US49270404 A US 49270404A US 2005006086 A1 US2005006086 A1 US 2005006086A1
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US
United States
Prior art keywords
separator
gas
pipeline
fed
installation
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
US10/492,704
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English (en)
Inventor
Per Gramme
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.)
Norsk Hydro ASA
Original Assignee
Individual
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Filing date
Publication date
Application filed by Individual filed Critical Individual
Assigned to NORSK HYDRO ASA reassignment NORSK HYDRO ASA ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: GRAMME, PER EIVIND
Publication of US20050006086A1 publication Critical patent/US20050006086A1/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
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D17/00—Separation of liquids, not provided for elsewhere, e.g. by thermal diffusion
    • B01D17/02—Separation of non-miscible liquids
    • B01D17/0208—Separation of non-miscible liquids by sedimentation
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D17/00—Separation of liquids, not provided for elsewhere, e.g. by thermal diffusion
    • B01D17/02—Separation of non-miscible liquids
    • B01D17/04—Breaking emulsions
    • B01D17/044—Breaking emulsions by changing the pressure
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D17/00—Separation of liquids, not provided for elsewhere, e.g. by thermal diffusion
    • B01D17/02—Separation of non-miscible liquids
    • B01D17/04—Breaking emulsions
    • B01D17/045—Breaking emulsions with coalescers
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D17/00—Separation of liquids, not provided for elsewhere, e.g. by thermal diffusion
    • B01D17/06—Separation of liquids from each other by electricity
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D19/00—Degasification of liquids
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D19/00—Degasification of liquids
    • B01D19/0068—General arrangements, e.g. flowsheets

Definitions

  • the present invention concerns an installation arranged on the sea bed for the separation of fluids.
  • Fluids in this context means oil, gas and water or mixtures of these substances, possibly containing particles of sand, that are produced in connection with the extraction of oil/gas from wells in geological formations beneath the sea bed.
  • PCT/NO98/00085 concerns the separation of fluids in pipe separators in horizontal sections of wells.
  • the main reason why it is possible to achieve quantitative oil and water separation in a pipe separator installed in a horizontal well is related to the good separation properties of the well fluid.
  • the main reason for the good separation properties in the well is that the interface between the oil and water is relatively free of surfactants that can stabilise the interface and thus impede drop growth and the formation of a free aqueous phase in connection with coalescence. This is what makes it possible to use such separation solutions in the well, where controlled use of a de-emulsifier is very complicated or virtually impossible.
  • the separation properties of the oil/water fluid will always be poorer than under down-hole conditions. This difference can be compensated for by placing the separator upstream of the choke when using a de-emulsifier or ultrasound.
  • the pipe separator can be a transport pipeline designed with a slightly larger diameter than necessary or as an extended section of the transport pipeline.
  • the pipe separator is an effective solution to the design problem caused by high external liquid pressure at large sea depths.
  • the technology can be combined with CEC (Compact Electrostatic Coalescer) concepts based on pipe coalescers, which allows it to be used at larger sea depths. For fluids that are more difficult to separate, a CEC is necessary to achieve the product specifications of the oil phase and to eliminate downstream hydrate precipitation problems in this flow.
  • the pipe separator produces bulk oil/water separation. For lighter, simpler crude oil systems, the separator will be able to separate the fluid down to product specifications. In this case, no further separation unit is required in the process.
  • the pipe separator is designed as follows. The last part of the transport pipeline from the well head to the processing template is designed as a long, thin pipe separator. On account of its small pipe diameter (in the order of 0.5 m), the separator can be operated at high external pressure and low internal pressure. The separator is therefore particularly well suited for large sea depths. It is important for the water quality from the separator to be as good as possible in order to avoid, as far as possible, any further purification before injection/discharge.
  • the separator can therefore be fitted with a mechanical ultrasound-based emulsion destabilisation system instead of using a chemical de-emulsifier.
  • This solution will be able to produce a water quality that is suitable for reinjection ( ⁇ 1000 ppm) and possibly for discharge into the sea ( ⁇ 40 ppm).
  • a particularly favourable position for the pipe separator will be at the well head before any pressure relief.
  • the separator is designed as a three-phase separator with configuration options that allow for separate removal of gas, oil and water or, alternatively, gas/oil as a common flow and water as a separate flow.
  • the separator can be fitted with an ultrasound-based destabilisation system for the emulsion layer at the oil/water interface (as an alternative to the use of chemicals to break up emulsions).
  • the separator is also fitted with a double set of level profile meters (alternatives: gamma, capacitance and ultrasound).
  • the end of the pipe separator is connected to the template either directly or via flexible hoses.
  • FIG. 1 shows an installation on the sea bed with a pipe separator for gas/liquid separation.
  • FIG. 2 shows a first alternative embodiment of an installation with a pipe separator for gas/oil/water separation.
  • FIG. 3 shows a second alternative embodiment of an installation with two pipe separators in series, the first for gas/liquid separation and the second for oil/water separation.
  • FIG. 4 shows a third alternative embodiment of an installation with a pipe separator for gas/oil/water separation followed by a compact electrostatic coalescer and subsequently a pipe separator for oil/water separation.
  • FIG. 5 shows a fourth alternative installation with a pipe separator for gas/oil/water separation followed by a compact electrostatic coalescer and subsequently a pipe separator for oil/water separation.
  • a gas dehydration unit consisting of a pipe contactor and a gas/liquid separator in connection with the first pipe separator.
  • FIG. 6 shows a fifth embodiment which is based on the solution shown in FIG. 4 , but which is adapted for situations in which two or more wells produce different quantities of oil/water/gas.
  • FIG. 1 shows an installation arranged on the sea bed with a separator in the form of a pipe (pipe separator) 1 for gas/liquid separation that is connected to a well head 2 .
  • a separator in the form of a pipe (pipe separator) 1 for gas/liquid separation that is connected to a well head 2 .
  • This is a simple solution designed for use for oil/gas wells in which small quantities of water are produced.
  • the separated gas is removed in a pipe 3 and fed up to a platform, a production ship, etc. on the surface of the sea or a collecting pipeline that feeds the gas onto shore.
  • the liquid is removed in a pipe 4 , and a pump 5 pumps it up to the surface or onto shore as for the gas.
  • FIG. 2 shows a similar installation to that in FIG. 1 .
  • the separator here also separates out water that is fed via a pipe 6 to a pump 7 and back to the reservoir.
  • FIG. 3 shows a sea bed installation designed for conditions with a lot of gas in relation to liquid.
  • the solution is like that in FIG. 1 but the liquid (oil and water) that is separated out in a first separator 1 is fed to a second separator 8 where the oil is fed to the surface via the pipe 4 and the pump 5 , while the water is reinjected by means of the pump 7 via the pipe 6 .
  • FIG. 4 shows a sea bed processing plant designed for heavier oils and represents a further development of the installation shown in FIG. 3 .
  • the pipe separator 1 which, in this case, is designed for gas/oil/water separation, is connected to the well head 2 .
  • the gas is removed in the pipe 3 and fed to the surface.
  • the oil and water proceed to a compact electrostatic coalescer (CEC) 9 that increases the drop size of the water.
  • CEC compact electrostatic coalescer
  • the oil and water are then separated in a second pipe separator 8 for oil/water separation.
  • the oil is removed in the pipe 4 and pumped to the surface by the oil pump 5 , while the water is reinjected via the pipe 6 and the reinjection pump 7 .
  • FIG. 5 shows a sea bed installation that, in addition to that which is shown in FIG. 4 , has a gas dehydration unit.
  • the gas that is separated out in the first separator 1 is fed first to a gas dehydration reactor 11 .
  • glycol is added that “reacts with” the water in the gas.
  • the gas and the liquid are then fed to a third separator 12 , which, in turn, separates out the gas, which is fed to the surface via a pipe 14 , while the liquid is fed to a pump 16 and on to the surface.
  • FIG. 6 shows an example based on the solution shown in FIG. 4 , but which is adapted for a situation in which different quantities of oil, gas and water are produced in different ratios from two or more wells.
  • oil/gas/water are separated in a first separator 1 and oil/water in a second separator 12 with an intermediate coalescer 9 , as explained previously.
  • Down-hole separation takes place in a second well 20 .
  • Water separated out from the first separator 2 , the second separator 12 and the down-hole separator 18 is fed via respective pipes 21 , 22 , 23 to a buffer tank 18 for reinjection water.
  • the water in the tank 18 is reinjected into the reservoir by means of a pump 19 via the pipe/well 6 .
  • the pipe separator tolerates high internal and external pressure and therefore allows the following processing tasks to take place at large sea depths:
  • the pipe separator tolerates a high internal process pressure and can therefore be installed to advantage upstream of a choke valve on the well head.
  • the high process pressure will improve the phase separation properties and allow reduced use of de-emulsifier or chemical-free separation, depending on the fluid properties.
  • sea bed processing with removal of water to 0.5%, performed at a high system pressure (i.e. lower pH in the aqueous phase on account of more CO in the aqueous phase), will eliminate problematic precipitation of calcium naphthenate or expensive topside installations designed to handle calcium naphthenate precipitation.

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  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Mining & Mineral Resources (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Fluid Mechanics (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Physical Water Treatments (AREA)
  • Separation Using Semi-Permeable Membranes (AREA)
  • Pipeline Systems (AREA)
  • Centrifugal Separators (AREA)
  • Earth Drilling (AREA)
  • Physical Or Chemical Processes And Apparatus (AREA)
  • Cleaning Or Clearing Of The Surface Of Open Water (AREA)
  • Drying Of Gases (AREA)
  • External Artificial Organs (AREA)
  • Electrical Discharge Machining, Electrochemical Machining, And Combined Machining (AREA)
US10/492,704 2001-10-17 2002-10-14 Installation for the separation of fluids Abandoned US20050006086A1 (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
NO20015048A NO316837B1 (no) 2001-10-17 2001-10-17 Anordning for separasjon av fluider
NO20015048 2001-10-17
PCT/NO2002/000370 WO2003033872A1 (fr) 2001-10-17 2002-10-14 Installation permettant de separer des fluides

Publications (1)

Publication Number Publication Date
US20050006086A1 true US20050006086A1 (en) 2005-01-13

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Family Applications (1)

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US10/492,704 Abandoned US20050006086A1 (en) 2001-10-17 2002-10-14 Installation for the separation of fluids

Country Status (12)

Country Link
US (1) US20050006086A1 (fr)
EP (1) EP1438484B1 (fr)
CN (1) CN1330849C (fr)
AT (1) ATE349600T1 (fr)
AU (1) AU2002341443B2 (fr)
BR (1) BR0213313B1 (fr)
CA (1) CA2463692C (fr)
DE (1) DE60217148T2 (fr)
EA (1) EA005616B1 (fr)
MX (1) MXPA04003490A (fr)
NO (1) NO316837B1 (fr)
WO (1) WO2003033872A1 (fr)

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US20060124313A1 (en) * 2002-08-16 2006-06-15 Gramme Per E Pipe separator for the separation of fluids, particularly oil, gas and water
WO2007085900A3 (fr) * 2006-01-26 2007-12-06 Aker Kvaerner Process Systems Séparateur de fluides polyphasiques
NO326080B1 (no) * 2005-11-11 2008-09-15 Norsk Hydro Produksjon As Arrangement for deling av bronnstrom og separasjonssystem
US20090126927A1 (en) * 2005-02-11 2009-05-21 Per Eivind Gramme Method and Equipment for the Reduction of Multiple Dispersions
US20090145832A1 (en) * 2005-05-02 2009-06-11 Per Eivind Gramme Pipe separator
US7617940B2 (en) 2005-02-18 2009-11-17 Norsk Hydro Asa Arrangement related to a separator for the cleaning of such separator
US20100126925A1 (en) * 2006-11-20 2010-05-27 Liv Thorsen Flotation device
US20110127029A1 (en) * 2009-12-02 2011-06-02 Technology Commercialization Corp. Dual pathway riser and its use for production of petroleum products in multi-phase fluid pipelines
US20120000643A1 (en) * 2008-09-24 2012-01-05 Statoil Asa Gas-liquid separator
US8146667B2 (en) * 2010-07-19 2012-04-03 Marc Moszkowski Dual gradient pipeline evacuation method
US8333825B2 (en) 2007-10-12 2012-12-18 Caltec Limited Apparatus for and method of separating multi-phase fluids
WO2015167778A2 (fr) 2014-04-29 2015-11-05 Exxonmobil Upstream Research Company Système de séparation multiphase
WO2015114275A3 (fr) * 2014-01-30 2015-11-05 Total Sa Systeme de traitement d'un melange issu d'un puits de production
WO2015118072A3 (fr) * 2014-02-05 2015-12-10 Statoil Petroleum As Traitement sous-marin
US9359878B2 (en) * 2014-03-12 2016-06-07 Exxonmobil Upstream Research Company Split flow pipe separator
US9371724B2 (en) 2012-07-27 2016-06-21 Exxonmobil Upstream Research Company Multiphase separation system
US20170145803A1 (en) * 2015-11-19 2017-05-25 Norman K. Yeh Compact Subsea Dehydration
US10023811B2 (en) 2016-09-08 2018-07-17 Saudi Arabian Oil Company Integrated gas oil separation plant for crude oil and natural gas processing
US10046251B2 (en) 2014-11-17 2018-08-14 Exxonmobil Upstream Research Company Liquid collection system
US10130897B2 (en) 2013-01-25 2018-11-20 Exxonmobil Upstream Research Company Contacting a gas stream with a liquid stream
US10155193B2 (en) 2013-05-09 2018-12-18 Exxonmobil Upstream Research Company Separating impurities from a gas stream using a vertically oriented co-current contacting system
US10246983B2 (en) * 2016-07-28 2019-04-02 Exxonmobil Upstream Research Systems and methods for achieving three-phase separation and core annular flow in pipelines
US10260010B2 (en) 2017-01-05 2019-04-16 Saudi Arabian Oil Company Simultaneous crude oil dehydration, desalting, sweetening, and stabilization
US10300429B2 (en) 2015-01-09 2019-05-28 Exxonmobil Upstream Research Company Separating impurities from a fluid stream using multiple co-current contactors
US10343107B2 (en) 2013-05-09 2019-07-09 Exxonmobil Upstream Research Company Separating carbon dioxide and hydrogen sulfide from a natural gas stream using co-current contacting systems
US10391442B2 (en) 2015-03-13 2019-08-27 Exxonmobil Upstream Research Company Coalescer for co-current contractors
US20200018146A1 (en) * 2016-09-30 2020-01-16 Seabed Separation As Method and System for Separating Oil Well Substances
US10717039B2 (en) 2015-02-17 2020-07-21 Exxonmobil Upstream Research Company Inner surface features for co-current contractors
US10876052B2 (en) 2017-06-20 2020-12-29 Exxonmobil Upstream Research Company Compact contacting systems and methods for scavenging sulfur-containing compounds
US11000795B2 (en) 2017-06-15 2021-05-11 Exxonmobil Upstream Research Company Fractionation system using compact co-current contacting systems
US11000797B2 (en) 2017-08-21 2021-05-11 Exxonmobil Upstream Research Company Integration of cold solvent and acid gas removal
US11260342B2 (en) 2017-06-15 2022-03-01 Exxonmobil Upstream Research Company Fractionation system using bundled compact co-current contacting systems
US11268368B2 (en) * 2017-04-05 2022-03-08 Equinor Energy As Fluid flow conditioning
EP3500726B1 (fr) * 2016-08-19 2022-06-08 Trevelyan Trading Ltd Dispositif de drainage pour pipeline sous-marin
US12065908B2 (en) 2022-03-14 2024-08-20 Marine Well Containment Company Advanced extended flowback system

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JP2005101555A (ja) * 2003-08-28 2005-04-14 Mitsubishi Chemicals Corp 有機電界効果トランジスタ
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NO329480B1 (no) 2005-03-16 2010-10-25 Norsk Hydro As Anordning ved en rorseparator
US7854849B2 (en) 2006-10-10 2010-12-21 Multiphase Systems Integration Compact multiphase inline bulk water separation method and system for hydrocarbon production
FR2911794B1 (fr) * 2007-01-26 2009-12-18 Doris Engineering Procede et dispositif de separation des phases d'un fluide multiphasique.
NO328328B1 (no) * 2007-03-20 2010-02-01 Fmc Kongsberg Subsea As Undervanns separasjonsanlegg.
CN101678245A (zh) * 2007-04-18 2010-03-24 国际壳牌研究有限公司 用于分离油/水混合物的方法和装置
NO332062B1 (no) * 2008-02-28 2012-06-11 Statoilhydro Asa Sammenstilling for separasjon av en flerfasestrom
NO20120188A1 (no) 2012-02-23 2013-08-26 Fmc Kongsberg Subsea As Fremgangsmate og system for a tilveiebringe brenselgass til en toppside-fasilitet
CN104747162B (zh) * 2015-01-28 2017-11-03 中国石油大学(华东) 深海多相多级分离回注系统
US9957447B2 (en) 2015-12-22 2018-05-01 Cameron Solutions, Inc. Electrostatic technology system and process to dehydrate crude oil in a crude oil storage tank of a floating production storage and offloading installation
US9957446B2 (en) 2015-12-22 2018-05-01 Cameron Solutions, Inc. Topside oil production equipment system for reduction in space and weight
GB2561568A (en) 2017-04-18 2018-10-24 Subsea 7 Norway As Subsea processing of crude oil
GB2561570B (en) 2017-04-18 2020-09-09 Subsea 7 Norway As Subsea processing of crude oil
CA3069151A1 (fr) 2017-07-12 2019-01-17 Conocophillips Company Procedes d'elimination d'huile a partir de courants d'eau separes
NO20231261A1 (en) 2022-11-22 2024-05-23 Petroleo Brasileiro S A – Petrobras Control and management system of multiphase streams in subsea oil and gas production modules
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Cited By (59)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20060124313A1 (en) * 2002-08-16 2006-06-15 Gramme Per E Pipe separator for the separation of fluids, particularly oil, gas and water
US7516794B2 (en) 2002-08-16 2009-04-14 Norsk Hydro Asa Pipe separator for the separation of fluids, particularly oil, gas and water
US7730942B2 (en) 2005-02-11 2010-06-08 Norsk Hydro Asa Method and equipment for the reduction of multiple dispersions
US20090126927A1 (en) * 2005-02-11 2009-05-21 Per Eivind Gramme Method and Equipment for the Reduction of Multiple Dispersions
US7617940B2 (en) 2005-02-18 2009-11-17 Norsk Hydro Asa Arrangement related to a separator for the cleaning of such separator
AU2006214866B2 (en) * 2005-02-18 2011-06-16 Equinor Energy As Arrangement related to a separator for the cleaning of such separator
US20090145832A1 (en) * 2005-05-02 2009-06-11 Per Eivind Gramme Pipe separator
NO326080B1 (no) * 2005-11-11 2008-09-15 Norsk Hydro Produksjon As Arrangement for deling av bronnstrom og separasjonssystem
US20110139625A1 (en) * 2006-01-26 2011-06-16 Richard Arntzen Multiphase Fluid Separator
WO2007085900A3 (fr) * 2006-01-26 2007-12-06 Aker Kvaerner Process Systems Séparateur de fluides polyphasiques
US20100126925A1 (en) * 2006-11-20 2010-05-27 Liv Thorsen Flotation device
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CA2463692A1 (fr) 2003-04-24
EA200400541A1 (ru) 2004-08-26
CN1330849C (zh) 2007-08-08
DE60217148D1 (de) 2007-02-08
NO316837B1 (no) 2004-05-24
NO20015048D0 (no) 2001-10-17
AU2002341443B2 (en) 2008-02-14
CA2463692C (fr) 2011-03-29
MXPA04003490A (es) 2004-07-30
DE60217148T2 (de) 2007-09-27
EP1438484B1 (fr) 2006-12-27
CN1571877A (zh) 2005-01-26
BR0213313B1 (pt) 2012-08-21
ATE349600T1 (de) 2007-01-15
EA005616B1 (ru) 2005-04-28
WO2003033872A1 (fr) 2003-04-24
BR0213313A (pt) 2004-10-13
EP1438484A1 (fr) 2004-07-21
NO20015048L (no) 2003-04-22

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