EP3119984A1 - Systèmes de production de condensats gazeux fonctionnant avec de longues distances de décalage - Google Patents

Systèmes de production de condensats gazeux fonctionnant avec de longues distances de décalage

Info

Publication number
EP3119984A1
EP3119984A1 EP15712495.9A EP15712495A EP3119984A1 EP 3119984 A1 EP3119984 A1 EP 3119984A1 EP 15712495 A EP15712495 A EP 15712495A EP 3119984 A1 EP3119984 A1 EP 3119984A1
Authority
EP
European Patent Office
Prior art keywords
subsea
long offset
production
gas condensate
production system
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.)
Withdrawn
Application number
EP15712495.9A
Other languages
German (de)
English (en)
Inventor
James George Broze
Gaurav Bhatnagar
Karthik Ramanathan
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.)
Shell Internationale Research Maatschappij BV
Original Assignee
Shell Internationale Research Maatschappij BV
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 Shell Internationale Research Maatschappij BV filed Critical Shell Internationale Research Maatschappij BV
Publication of EP3119984A1 publication Critical patent/EP3119984A1/fr
Withdrawn legal-status Critical Current

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
    • E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • 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
    • E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
    • E21B43/0107—Connecting of flow lines to offshore structures
    • 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
    • E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
    • E21B43/017—Production satellite stations, i.e. underwater installations comprising a plurality of satellite well heads connected to a central station
    • E21B43/0175—Hydraulic schemes for production manifolds
    • 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
    • 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
    • E21B43/40—Separation associated with re-injection of separated materials

Definitions

  • the present disclosure relates generally to long offset gas condensate production systems. More specifically, in certain embodiments the present disclosure relates to long offset gas condensate production systems capable of transporting gas and condensate across subsea floors and associated methods.
  • Flow assurance management may include ensuring that the unprocessed well fluid are able to reach the process facility, arrive at the process facility above critical temperatures (such as the wax appearance temperature or cloud point and the hydrate equilibrium temperature), can be made to flow again after planned or unplanned shutdown (particularly with respect to clearing hydrate blockages), avoid hydrates, wax, asphaltene, scale, sand, and other undesirable contents from building up in the flowline, and can be made to flow at a range of driving pressures, flowrates, and compositions.
  • critical temperatures such as the wax appearance temperature or cloud point and the hydrate equilibrium temperature
  • Typical methods used to achieve the many different demands of flow assurance may include using highly insulated flowlines, pipe-in-pipe flowlines, active heating of flowlines, and dual flowlines. These approaches, however, may have high costs.
  • the oil industry is continually attempting to increase tieback distances and at the same time reduce the costs of those tieback systems.
  • the challenge of having longer tieback distances while at the same time achieving acceptable costs is proving difficult for the industry, especially because subsea tiebacks tend to be the approach used for the smaller reservoirs (which demand lower costs.)
  • Deeper water may also exacerbate the difficulties of subsea tie backs with the added disadvantage that it is much easier for hydrates that can block the flowlines to form in deep water.
  • Flow assurance management may be especially problematic with fluids with high concentrations of water.
  • the present disclosure relates generally to long offset gas condensate production systems. More specifically, in certain embodiments the present disclosure relates to long offset gas condensate production systems capable of transporting gas and condensate across subsea floors and associated methods.
  • the present disclosure provides a long offset gas condensate production system comprising: one or more subsea production wells; a subsea cooler, and a subsea separator.
  • the present disclosure provides a long offset gas condensate production system comprising: one or more subsea production wells; a subsea separator; a subsea cooler; and a subsea compressor.
  • the present disclosure provides a method of transporting gas and condensate across a subsea floor comprising: providing a long offset gas condensate production system; providing a subsea production stream, cooling the subsea production stream to form a cooled subsea production stream, separating the cooled subsea production stream into a produced water stream and a combined gas and condensate stream, and transporting the combined gas and condensate stream across the subsea floor.
  • Figure 1 is an illustration of a long offset condensate production system in accordance with an embodiment of the present disclosure.
  • Figure 2 is an illustration of a long offset gas condensate production system in accordance with an embodiment of the present disclosure.
  • the present disclosure relates generally to long offset gas condensate production systems. More specifically, in certain embodiments the present disclosure relates to long offset gas condensate production systems capable of transporting gas and condensate across subsea floors and associated methods.
  • Figure 1 illustrates a long offset gas condensate production system 100 comprising a subsea production well 110; a subsea cooler 120; and a subsea separator 130.
  • subsea production well 110 may comprise a single subsea production well 110 or multiple subsea production wells 110.
  • long offset gas condensate production system 100 may comprise one, two, three, four, five, or more subsea production wells 110.
  • each of the multiple subsea production wells 110 may be connected to a subsea manifold 111 by one or more flowlines 112.
  • subsea production well 110 may comprise a gas condensate well.
  • subsea manifold 111 may comprise any conventional subsea manifold.
  • flowlines 112 may comprise any conventional subsea flowline. In certain embodiments, flowlines 112 may comprise non-CRA materials
  • subsea cooler 120 may comprise any conventional subsea cooler.
  • subsea cooler 120 may be used in several different configurations to achieve different flow assurance benefits. For example, as shown in Figure 1, subsea cooler 120 may be directly connected to a flowline 113 from subsea manifold 111. Alternatively, not illustrated in Figure 1, subsea cooler 120 may be connected to a well stream directly from a subsea production well. In these configurations, the subsea cooler may be used to cool a subsea production stream before it enters subsea separator 130.
  • long offset gas condensate system may not comprise a subsea cooler before subsea separator.
  • long offset gas condensate system may comprise a subsea cooler without subsea separator and/or a compressor.
  • flowline 121 from subsea cooler 120 may be connected directly to subsea separator 130.
  • a flowline from manifold 111 or one or more individual wells 110 may be connected directly to subsea separator 120.
  • the subsea separator 130 may be a three-phase separator. In certain embodiments subsea separator 130 may be a two-phase separator. In certain embodiments, subsea separator 130 may be used capable of separating a production stream into a gas stream, a condensate stream, and a water stream. In certain embodiments, subsea separator 130 may comprise a gas flowline 132, a condensate flowline 133, and a water flowline 134.
  • the water stream separated from the production stream within subsea separator 130 may be disposed of or injected into a reservoir.
  • water flowline 134 may be connected to a subsea water injection well 140.
  • pump 135 may facilitate the flow of the water stream within water flowline 134 water from subsea separation 130 to subsea water injection well 140.
  • gas flowline 132 and condensate flowline 133 may combined to form a combined gas and condensate flowline 136.
  • combined gas and condensate flowline 136 may comprise a DLC coated flowline.
  • combined gas and condensate flowline 136 may comprise an electrically heated flowline.
  • combined gas and condensate flowline 136 may be capable of transporting gas and condensate across the subsea floor to an onshore location.
  • long offset gas condensate production system 100 may comprise subsea pig launcher 150.
  • subsea pig launcher 150 may be capable of launching pigs within combined gas and condensate flowline 136.
  • long offset gas condensate production system 100 may comprise paraffin inhibitor injection point 161.
  • paraffin inhibitor injection point 161 may be located in combined gas and condensate flowline 136.
  • a paraffin inhibitor may be injected into the subsea system at paraffin injection point 161 to mitigate wax deposition in flowlines.
  • long offset gas condensate production system 200 may comprise any combination of features discussed above with respect to long offset gas condensate production system 100.
  • long offset gas condensate production system 200 may comprise a subsea production well 210; a subsea cooler 220; a subsea separator 230, and a subsea water injection well 240.
  • subsea production well 210 may comprise any combination of features described above with respect to subsea production well 210.
  • subsea production system 200 may comprise multiple wells 210 connected to a manifold 211 by flowlines 213.
  • subsea cooler 220 may comprise any combination of features discussed above with respect to subsea cooler 120. As can be seeing in Figure 2, in certain embodiments, subsea cooler 220 may be fluidly connected to subsea manifold 111 by a flowline 212.
  • subsea separator 230 may comprise any combination of features discussed above with respect to subsea separator 130. As can be seen in Figure 2, in certain embodiments, subsea separator 230 may be connected to a subsea water injection well 240 by a water flowline 234. In certain embodiments, subsea separator 230 may also comprise a gas flowline 232 and a condensate flowline 233. In certain embodiments, gas flowline 232 and condensate flowline 233 may be combined to form a combined gas and condensate flowline 236 [0032] In certain embodiments, a subsea compressor 250 may be connected to combined gas and condensate flowline 236.
  • subsea compressor 250 may be either dry gas or wet gas compressor. In certain embodiments, subsea compressor 250 may comprise a recycle stream 251. In certain embodiments, subsea compressor 250 may comprise a subsea cooler 252. In certain embodiments, the subsea cooler may be used to cool the combined gas and condensate flowline 236, recycle stream 251, or compressed gas and condensate flowline 237.
  • compressed gas and condensate flowline 237 may comprise a DLC coated flowline. In certain embodiments, compressed gas and condensate flowline 237 may comprise an electrically heated flowline. In certain embodiments, compressed gas and condensate flowline 237 may be capable of transporting gas and condensate across the subsea floor to an onshore location.
  • long offset gas condensate production system 200 may comprise subsea pig launcher 260.
  • subsea pig launcher 260 may be capable of launching pigs within compressed gas and condensate flowline 237.
  • long offset gas condensate production system 200 may comprise paraffin inhibitor injection point 261.
  • paraffin inhibitor injection point 261 may be located in compressed gas and condensate flowline 237.
  • a paraffin inhibitor may be injected into the subsea system at paraffin injection point 261 to mitigate wax deposition in flowlines.
  • the present disclosure provides a method of transporting gas and condensate across a subsea floor.
  • the method may comprise: providing a long offset gas condensate production system; providing a subsea production stream, cooling the subsea product stream to form a cooled subsea production stream, separating the cooled subsea production stream into a produced water stream and a combined gas and condensate stream and, and transporting the gas and condensate stream across the subsea floor.
  • the long offset gas condensate production system may comprise any combination of features discussed above with respect to long offset gas condensate production systems 100 and 200.

Landscapes

  • 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)
  • Physical Or Chemical Processes And Apparatus (AREA)
  • Heat-Exchange Devices With Radiators And Conduit Assemblies (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

La présente invention concerne un système de production de condensats de gaz ayant de longues distances de décalage qui comprend: un puits de production sous-marin; un séparateur sous-marin; et un refroidisseur sous-marin.
EP15712495.9A 2014-03-17 2015-03-13 Systèmes de production de condensats gazeux fonctionnant avec de longues distances de décalage Withdrawn EP3119984A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201461954254P 2014-03-17 2014-03-17
PCT/US2015/020323 WO2015142629A1 (fr) 2014-03-17 2015-03-13 Systèmes de production de condensats gazeux fonctionnant avec de longues distances de décalage

Publications (1)

Publication Number Publication Date
EP3119984A1 true EP3119984A1 (fr) 2017-01-25

Family

ID=52780046

Family Applications (1)

Application Number Title Priority Date Filing Date
EP15712495.9A Withdrawn EP3119984A1 (fr) 2014-03-17 2015-03-13 Systèmes de production de condensats gazeux fonctionnant avec de longues distances de décalage

Country Status (6)

Country Link
US (1) US20170016309A1 (fr)
EP (1) EP3119984A1 (fr)
CN (1) CN106103885A (fr)
AU (1) AU2015231769A1 (fr)
BR (1) BR112016021511A2 (fr)
WO (1) WO2015142629A1 (fr)

Families Citing this family (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
BR102015003532A2 (pt) * 2015-02-19 2016-09-13 Fmc Technologies Do Brasil Ltda unidades de separação gás-líquido e compressão/bombeio montáveis em poço de produção e poço de injeção
WO2018045357A1 (fr) * 2016-09-02 2018-03-08 Fmc Technologies, Inc. Architecture améliorée de champ sous-marin
CN110984961A (zh) * 2019-12-25 2020-04-10 西南石油大学 一种两相气藏水平井温度模拟实验装置及其方法

Family Cites Families (12)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
MY123548A (en) * 1999-11-08 2006-05-31 Shell Int Research Method and system for suppressing and controlling slug flow in a multi-phase fluid stream
GB0008300D0 (en) * 2000-04-05 2000-05-24 Ingen Process Limited Method and apparatus
US6672391B2 (en) * 2002-04-08 2004-01-06 Abb Offshore Systems, Inc. Subsea well production facility
NO326079B1 (no) * 2006-07-07 2008-09-15 Shell Int Research Fremgangsmate for a behandle og separere en flerfaset bronnstromblanding.
GB2465118B (en) * 2007-09-25 2011-11-02 Exxonmobil Upstream Res Co Method for managing hydrates in subsea production line
CN201292828Y (zh) * 2008-09-09 2009-08-19 中国石化集团胜利石油管理局钻井工艺研究院 深水水下储油石油生产装置
BRPI1007044B1 (pt) * 2009-01-16 2019-08-06 Shell Internationale Research Maatschappij B.V. Sistema de produção submarina, e, método para produzir hidrocarbonetos
RU2553664C2 (ru) * 2010-03-11 2015-06-20 Синвент Ас Обработка потока жидких углеводородов, содержащего воду
CN102859114B (zh) * 2010-04-27 2016-10-12 国际壳牌研究有限公司 利用分离和增压来改型水下设备的方法
GB2493749B (en) * 2011-08-17 2016-04-13 Statoil Petroleum As Improvements relating to subsea compression
NO335391B1 (no) * 2012-06-14 2014-12-08 Aker Subsea As Bruk av brønnstrøms varmeveksler for strømningssikring
WO2014031728A1 (fr) * 2012-08-23 2014-02-27 Shell Oil Company Système et procédé servant à la séparation de fluides produits à partir d'un puits de forage

Also Published As

Publication number Publication date
US20170016309A1 (en) 2017-01-19
AU2015231769A1 (en) 2016-09-01
CN106103885A (zh) 2016-11-09
BR112016021511A2 (pt) 2017-08-15
WO2015142629A1 (fr) 2015-09-24

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