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WO1998037307A1 - Appareil de commande et surveillance d'un separateur huile-eau de fond de puits - Google Patents

Appareil de commande et surveillance d'un separateur huile-eau de fond de puits Download PDF

Info

Publication number
WO1998037307A1
WO1998037307A1 PCT/US1998/002621 US9802621W WO9837307A1 WO 1998037307 A1 WO1998037307 A1 WO 1998037307A1 US 9802621 W US9802621 W US 9802621W WO 9837307 A1 WO9837307 A1 WO 9837307A1
Authority
WO
WIPO (PCT)
Prior art keywords
outlet conduit
separator
pressure
conduit
inlet
Prior art date
Application number
PCT/US1998/002621
Other languages
English (en)
Inventor
Chris Shaw
Michael H. Johnson
Wallace W. F. Leung
Original Assignee
Baker Hughes Incorporated
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 Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Priority to CA002281809A priority Critical patent/CA2281809A1/fr
Priority to AU62758/98A priority patent/AU6275898A/en
Publication of WO1998037307A1 publication Critical patent/WO1998037307A1/fr
Priority to NO994068A priority patent/NO994068L/no

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
    • 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
    • E21B43/38—Arrangements for separating materials produced by the well in the well
    • E21B43/385—Arrangements for separating materials produced by the well in the well by reinjecting the separated materials into an earth formation in the same well
    • 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
    • E21B43/35—Arrangements for separating materials produced by the well specially adapted for separating solids

Definitions

  • the invention relates generally to systems for separating water from hydrocarbons (e.g. oil) in a well and in particular to methods and apparatus for monitoring and controlling a downhole oil/water separator.
  • hydrocarbons e.g. oil
  • U.S. Patent 5,269, 1 53 discloses a downhole separation system which is shown in FIGURE 1 .
  • the well 1 3 comprises a downhole oil/water separation system including a cyclone separator 1 1 having a separation chamber 1 5 wherein liquids of different densities are separated .
  • Mixed liquids enter through inlet 1 7 at a high tangential speed so as to generate the required centrifugal force for subsequent separation and pass into separation chamber 1 5.
  • a first outlet 1 9 is provided for liquids having a first density and a second outlet 21 is provided for liquids having a second density.
  • a stream of mainly oil flows out of outlet 1 9 and along recovery conduit 27.
  • a steam of mainly water passes through outlet 21 into disposal conduit 33 and is injected into the formation through injection perforations 34.
  • the present invention is a computer controlled downhole oil/water separation system.
  • a hydrocyclone separator is positioned downhole for receiving production fluid and separating oil and water contained in the production fluid .
  • Sensors are positioned downhole for monitoring parameters and generating sensing signals corresponding to the parameters.
  • a microprocessor based controller receives the sensing signals and provides controlling signals to one or more control devices to optimize the operation of the downhole oil/water separation system.
  • the computer controlled downhole oil/water separation system reduces the amount of water pumped to the surface of the well.
  • the system can also detect upset conditions when the water percentage becomes too high and cease production from a zone before excessive water is pumped to the surface. .
  • By reducing the amount of water pumped to the surface the expense of processing and injecting water back into the formation is reduced and well profitability is enhanced.
  • FIGURE 1 is a diagram of a conventional downhole hydrocyclone separator
  • FIGURE 2 is a diagram of a downhole hydrocyclone separator system of the present invention.
  • FIGURE 3 is a block diagram of staged hydrocyclone separators in accordance with the present invention.
  • FIGURE 2 is a diagram of the oil/water separation system in accordance with the present invention .
  • the system includes a hydrocyclone separator 40.
  • the hydrocyclone separator has an inlet 42 for receiving production fluid containing a first liquid having a first density (e.g. oil) and a second liquid having a second density (e.g. water) .
  • the input production fluid is fed at a high tangential speed so as to generate the required centrifugal force for subsequent separation.
  • the hydrocyclone separator is made up of a first section 41 , a second section 43 and a third section 45.
  • the second section 43 has an apex angle of approximately 5-7 degrees.
  • the third section 45 is a shallow, conical tube having an apex angle of 3-5 degrees and increases the time for separation .
  • a first outlet conduit 44 is provided for the first liquid and a second outlet conduit 46 is provided for the second liquid .
  • the hydrocyclone separator 40 is similar to conventional liquid/liquid hydrocyclone separators in which the heavier liquid (e.g. water) is forced to the wall of the separator under centrifugal force and directed to the second outlet 46.
  • the lighter liquid e.g. oil
  • a pump 100 is located uphole in first outlet conduit 44 to pump the oil to the surface if required .
  • the production fluid is flows into the wells, for example through production perforations 50 formed in the well casing .
  • a pump 52 has pump inlets 54 through which production fluid is drawn and pumped along conduit 58 to the hydrocyclone inlet 42.
  • a motor 56 drives pump 52.
  • the motor 56 may be any known type of motor including electric, hydraulic or pneumatic or be located at the surface such as a surface driven PCP or rod pump motor (not shown) . As will be described below, the motor 56 is configured to respond to a controlling signal to change its RPM and thus the pump rate of pump 52.
  • Water is passed through second outlet conduit 46 and injected back into the formation at a different stratum different from the producing hydrocarbon formation along a line of demarcation or barrier 63 through injection perforations 60.
  • a packer 62 isolates the production perforations 50 from the injection perforations 60.
  • the downhole oil/water separation system includes a controller 70 which monitors parameters of the downhole oil/water separation system and controls operation of the system.
  • the controller 70 includes a microprocessor and other associated components such as memory, I/O ports, etc. that are known in the art and which can tolerate the harsh environment downhole (high temperature, corrosion, pressure, etc. ) . Sensors are employed throughout the downhole oil/water separation system for monitoring parameters of the system and forwarding sensing signals representative of these parameters to the controller 70.
  • the controller 70 may be located downhole as shown in FIGURE 2 or may be placed at the surface in which signals are transmitted across the formation through wires, cables, fiber optic or wireless transmission, such as telemetry.
  • An inlet sensor 72 is positioned at the inlet of the hydrocyclone separator 40, a first outlet sensor 74 is positioned in the first outlet conduit 44 and a second outlet sensor 76 is positioned in the second outlet conduit 46.
  • the sensors are connected to the controller 70 through wires 80, 81 and 82, respectively. It is understood that other communication techniques may be employed. For example, the sensors may also communicate with the controller 70 through telemetry thereby excluding the need for wires 80, 81 and 82.
  • Sensor 94 is coupled to pump 52 and controller 70 through wires or telemetry and monitors the intake pressure at pump 52.
  • the controller 70 produces controlling signals and provides the controlling signals to one or more control devices.
  • the control devices include the motor 56, a first control valve 90 positioned in the first outlet conduit 44, a second control valve 92 positioned in the second outlet conduit 46, an inlet control valve 93 positioned in the inlet of the separator 40 and pump 100.
  • the first control valve 90 may be eliminated and flow through first conduit 44 may be controlled directly by controlling pump 100 through wire 84a. Alternatively, pump 100 and first control valve 90 may be used in conjunction .
  • the controller 70 is connected to the control devices through wires 83, 84, 85, 87 and 84a, respectively. It is understood that other communication techniques may be employed .
  • the controller 70 may also communicate with the control devices through telemetry thereby eliminating the need for the wires.
  • the controller 70 may also communicate with the surface of the well over wire, fiber optics 86 or through telemetry.
  • the motor 56 may have a variety of configurations (electric, hydraulic, pneumatic, etc. ) and is adapted to adjust the motor in response to a controlling signal from controller 70.
  • the motor 56 affects the volumetric flow rate and pressure along conduit 58 and the downhole separator inlet 42.
  • the volumetric feed rate in turn affects the tangential speed and consequently the centrifugal gravity developed for separation.
  • An adjustable inlet valve 93 is installed at the inlet of the hydrocyclone separator.
  • the feed velocity and therefore the centrifugal force can be maintained constant or higher independent of the volumetric flow rate.
  • the valve opening 93 can be controlled by wire 87 from the controller 70.
  • the first control valve 90 and the second control valve 92 may have a variety of configurations, but must be able to incrementally open and close in response to controlling signals from the controller 70.
  • the inlet sensors 72 detect the flow rate, pressure, temperature and water percentage of the production fluid entering the inlet conduit 42. Based on these parameters, the controller 70 generates controlling signals and provides the controlling signals to the appropriate control device or control devices. For example, if the hydrocyclone separator is designed to optimally operate at a predetermined flow rate of inlet production fluid, the controller 70 can adjust the revolutions-per-minute (RPM) of motor 56 to establish the ideal inlet flow rate, and in combination in with the valve setting 93 which adjusts the flow area, the optimal centrifugal force can be established . Similarly the inlet pressure, inlet temperature and inlet water percentage are used to control the system. If the water percentage at the inlet becomes too high, it may be determined that the formation is no longer producing sufficient amounts of oil.
  • RPM revolutions-per-minute
  • the motor 56 may be increased to effect production of incremental oil.
  • the first outlet sensors 74 detect the pressure, temperature and water percentage at the first outlet conduit 44. Sensing signals corresponding to these parameters are provided to controller 70 and the controller 70 generates controlling signals and provides the controlling signals to the appropriate control device or control devices. The controller 70 controls the control devices so that the water percentage at first outlet conduit 44 is a minimum.
  • the second outlet sensors 76 monitor pressure, flow rate, water percentage, solid particle concentration and/or other water quality parameters, such as pH, at the second outlet conduit 46. The controller 70 receives sensing signals from sensors 76 and generates the necessary controlling signals. One or more of the control devices are controlled so that the water percentage in second outlet conduit 46 is optimized .
  • control processes are exemplary and are not intended to represent all the control processes that may be executed by the present invention.
  • the control processes may be used alone or in combination with other control processes.
  • the pump intake pressure is monitored by sensor 94 and a sensing signal is provided to the controller 70. Based on the pump intake pressure, the controller 70 sends controlling signals to the motor 56 to adjust the motor speed so that the pump intake pressure is minimized . By minimizing the pump 52 intake pressure, the well inflow, and thus well production, is maximized .
  • Another control process is based on the oil concentration in the second output conduit 46 sensed by sensors 76. If the oil concentration at sensor 76 increases, second control valve 92 should be incrementally closed and/or first control valve 90 may be incrementally opened . Alternatively, the speed of pump 1 00 may be increased . All of these adjustments have the effect of increasing the oil flow rate through first outlet conduit 44. However, in this process the water concentration in the first liquid output conduit 44 sensed by sensors 74 should be maintained at an acceptable low level. In yet another control process, the oil concentration at the inlet conduit
  • first control valve 90 is opened or the speed of pump 100 is increased to facilitate removal of the oil .
  • first control valve 90 is incrementally closed or the speed of pump 100 is reduced to prevent water for exiting through first outlet conduit 44.
  • the separator pressure differential ratio is monitored and adjusted dependent upon the oil concentration at inlet 42.
  • the separator pressure differential ratio is defined as: (inlet pressure at 42 - outlet pressure at 44)/(inlet pressure at 42 - outlet pressure at 46).
  • the ratio identifies what percentage of the liquid entering the separator at inlet 42 is distributed to the first outlet conduit 44 and the second outlet conduit 46.
  • the oil concentration at inlet 42 is monitored by sensors 72 and the first control valve 90 and/or pump 100 and the second control valve 92 are adjusted so that the separator pressure differential ratio is optimized for the given inlet oil concentration.
  • the cross section area of valve 93 can be reduced to generate a higher velocity and hence a higher centrifugal force for separation.
  • the controller 70 also signals the pump motor 56 to increase RPM to pump against the back pressure established by the further restriction from the inlet valve 93 given that the volumetric feeding rate is held constant.
  • the separator system shown in Fig. 2 may also be provided with a pump (not shown) driven by a suitable motor, such as electric, hydraulics or pneumatic (not shown) positioned in the conduit 46 and controlled by controller 70.
  • This pump increase the pressure of the water discharged from the separator 40 for reinjection into the formation .
  • This pump may be provided in addition to pumps 52 and 100, or in lieu of one or the other of these pumps.
  • the sensors 72, 74, 76 and 94 may of any suitable type such as fiber optic, infrared, or ultrasonic.
  • the present invention can also be modified to provide for the removal of solids from the production fluid containing solids, a first liquid (e.g. oil) and a second liquid (e.g. water) .
  • a flow through filter e.g. screen
  • staged hydrocyclone separators may be used as shown in FIGURE 3.
  • a feed conduit 200 carries production fluid containing solids, a first liquid and a second liquid .
  • a solid/liquid separator 202 separates the solids from the two liquids. The solids are output through solid outlet conduit 204 and the mixed liquids are output through conduit 206.
  • a liquid/liquid separator 208 operates in accordance with the system described above with reference to FIGURE 2 and outputs the first liquid through conduit 21 0 and the second liquid through conduit 21 2.
  • the present invention provides for intelligent control of a downhole oil/water separator by including sensors, control devices and a controller downhole with the separator.
  • the sensors monitor parameters of the separation system and the controller controls portions of the system to maximize oil/water separation.
  • the controller can also determine when the water percentage is so high that production from a particular zone should be discontinued . This prevents excess water from being pumped to the surface and reduces the costs associated with processing and injecting water from the surface back into the formation.

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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)
  • Centrifugal Separators (AREA)

Abstract

L'invention concerne un système informatisé (p. ex. intelligent) de séparation huile-eau de fond de puits. Un séparateur hydrocyclone (40) est utilisé au fond d'un puits pour séparer l'huile de l'eau. Des capteurs de fond de puits surveillent des paramètres associés au système de séparation huile-eau de fond de puits et émettent des signaux représentant les paramètres vers un dispositif de commande (70), lequel commande le fonctionnement du système par la production de signaux de commande et l'envoi de ceux-ci vers un ou plusieurs appareils de commande. La séparation huile-eau est optimisée et la rentabilité du puits est améliorée.
PCT/US1998/002621 1997-02-25 1998-02-05 Appareil de commande et surveillance d'un separateur huile-eau de fond de puits WO1998037307A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
CA002281809A CA2281809A1 (fr) 1997-02-25 1998-02-05 Appareil de commande et surveillance d'un separateur huile-eau de fond de puits
AU62758/98A AU6275898A (en) 1997-02-25 1998-02-05 Apparatus for controlling and monitoring a downhole oil/water separator
NO994068A NO994068L (no) 1997-02-25 1999-08-24 Anordning for styring og overvaaking av en nedihull olje/vann-separator

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US3807697P 1997-02-25 1997-02-25
US60/038,076 1997-02-25

Publications (1)

Publication Number Publication Date
WO1998037307A1 true WO1998037307A1 (fr) 1998-08-27

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Application Number Title Priority Date Filing Date
PCT/US1998/002621 WO1998037307A1 (fr) 1997-02-25 1998-02-05 Appareil de commande et surveillance d'un separateur huile-eau de fond de puits

Country Status (4)

Country Link
AU (1) AU6275898A (fr)
CA (1) CA2281809A1 (fr)
NO (1) NO994068L (fr)
WO (1) WO1998037307A1 (fr)

Cited By (23)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2345307A (en) * 1999-01-04 2000-07-05 Camco Int Dual electric submergible pumping system
US6250390B1 (en) 1999-01-04 2001-06-26 Camco International, Inc. Dual electric submergible pumping systems for producing fluids from separate reservoirs
WO2001071158A1 (fr) * 2000-03-20 2001-09-27 Kværner Oilfield Products As Système de production sous-marine
US6330913B1 (en) 1999-04-22 2001-12-18 Schlumberger Technology Corporation Method and apparatus for testing a well
US6347666B1 (en) 1999-04-22 2002-02-19 Schlumberger Technology Corporation Method and apparatus for continuously testing a well
US6357525B1 (en) 1999-04-22 2002-03-19 Schlumberger Technology Corporation Method and apparatus for testing a well
US6382315B1 (en) 1999-04-22 2002-05-07 Schlumberger Technology Corporation Method and apparatus for continuously testing a well
WO2003033871A1 (fr) * 2001-10-12 2003-04-24 Alpha Thames Ltd Systeme et procede destines a separer des fluides
US6575242B2 (en) 1997-04-23 2003-06-10 Shore-Tec As Method and an apparatus for use in production tests, testing an expected permeable formation
GB2384508A (en) * 1999-04-16 2003-07-30 Halliburton Energy Serv Inc Downhole separator for use in a subterrranean well and method
US7370701B2 (en) 2004-06-30 2008-05-13 Halliburton Energy Services, Inc. Wellbore completion design to naturally separate water and solids from oil and gas
US7429332B2 (en) 2004-06-30 2008-09-30 Halliburton Energy Services, Inc. Separating constituents of a fluid mixture
GB2448017A (en) * 2007-03-27 2008-10-01 Schlumberger Holdings Control of a downhole oil/water separation system
US7462274B2 (en) 2004-07-01 2008-12-09 Halliburton Energy Services, Inc. Fluid separator with smart surface
US7823635B2 (en) 2004-08-23 2010-11-02 Halliburton Energy Services, Inc. Downhole oil and water separator and method
GB2472151A (en) * 2007-03-27 2011-01-26 Schlumberger Holdings Method of operating a downhole oil water separator
WO2011081529A1 (fr) * 2009-12-29 2011-07-07 Aker Subsea As Commande de cyclone sous-marin
WO2011130783A1 (fr) * 2010-04-23 2011-10-27 Vulco S.A. Système de régulation de stabilité pour un hydrocyclone
WO2014070905A1 (fr) * 2012-10-31 2014-05-08 Halliburton Energy Services, Inc. Systèmes et procédés pour analyser des compositions d'écoulement de retour en temps réel
US8757256B2 (en) 2003-10-24 2014-06-24 Halliburton Energy Services, Inc. Orbital downhole separator
GB2514589A (en) * 2013-05-30 2014-12-03 Nat Oilwell Varco Lp A centrifuge
WO2025049282A1 (fr) * 2023-08-25 2025-03-06 Halliburton Energy Services, Inc. Séparateur de fluide de fond de trou dans un puits multilatéral de nouvelle entrée
WO2025049285A1 (fr) * 2023-08-25 2025-03-06 Halliburton Energy Services, Inc. Conception de séparateur de fluide de fond de trou dans un puits multilatéral

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CN101793138B (zh) * 2010-03-10 2013-06-26 大庆油田有限责任公司 水力旋流器与螺杆泵配合的井下油水分离方法
CN102701321B (zh) * 2012-05-31 2013-10-30 山东大学 一种油水分离及出油量远程定量多维监控系统
CN108252704B (zh) * 2017-12-29 2022-01-21 中国船舶重工集团公司第七一八研究所 一种泵出式小直径伽马能谱测井仪探头过线结构

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GB2194574A (en) * 1986-09-02 1988-03-09 Elf Aquitaine Device for regulating the rate of flow of water which is separated from its mixture with hydrocarbons and reinjected into the bottom of the well
GB2194575A (en) * 1986-09-02 1988-03-09 Elf Aquitaine Method of pumping hydrocarbons from a mixture of said hydrocarbons with an aqueous phase and installation for the carrying out of the method
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GB2194574A (en) * 1986-09-02 1988-03-09 Elf Aquitaine Device for regulating the rate of flow of water which is separated from its mixture with hydrocarbons and reinjected into the bottom of the well
GB2194575A (en) * 1986-09-02 1988-03-09 Elf Aquitaine Method of pumping hydrocarbons from a mixture of said hydrocarbons with an aqueous phase and installation for the carrying out of the method
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Cited By (50)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6575242B2 (en) 1997-04-23 2003-06-10 Shore-Tec As Method and an apparatus for use in production tests, testing an expected permeable formation
GB2345307B (en) * 1999-01-04 2003-05-21 Camco Int Dual electric submergible pumping system installation to simultaneously move fluid with respect to two or more subterranean zones
US6250390B1 (en) 1999-01-04 2001-06-26 Camco International, Inc. Dual electric submergible pumping systems for producing fluids from separate reservoirs
GB2345307A (en) * 1999-01-04 2000-07-05 Camco Int Dual electric submergible pumping system
GB2384508B (en) * 1999-04-16 2003-09-17 Halliburton Energy Serv Inc Downhole separator for use in a subterranean well and method
GB2384508A (en) * 1999-04-16 2003-07-30 Halliburton Energy Serv Inc Downhole separator for use in a subterrranean well and method
US6352110B1 (en) 1999-04-22 2002-03-05 Schlumberger Technology Corporation Method and apparatus for continuously testing a well
US6382315B1 (en) 1999-04-22 2002-05-07 Schlumberger Technology Corporation Method and apparatus for continuously testing a well
US6457521B1 (en) 1999-04-22 2002-10-01 Schlumberger Technology Corporation Method and apparatus for continuously testing a well
US6357525B1 (en) 1999-04-22 2002-03-19 Schlumberger Technology Corporation Method and apparatus for testing a well
US6347666B1 (en) 1999-04-22 2002-02-19 Schlumberger Technology Corporation Method and apparatus for continuously testing a well
US6330913B1 (en) 1999-04-22 2001-12-18 Schlumberger Technology Corporation Method and apparatus for testing a well
WO2001071158A1 (fr) * 2000-03-20 2001-09-27 Kværner Oilfield Products As Système de production sous-marine
US7093661B2 (en) 2000-03-20 2006-08-22 Aker Kvaerner Subsea As Subsea production system
WO2003033871A1 (fr) * 2001-10-12 2003-04-24 Alpha Thames Ltd Systeme et procede destines a separer des fluides
US7013978B2 (en) 2001-10-12 2006-03-21 Alpha Thames, Ltd. System and method for separating fluids
US8757256B2 (en) 2003-10-24 2014-06-24 Halliburton Energy Services, Inc. Orbital downhole separator
US7370701B2 (en) 2004-06-30 2008-05-13 Halliburton Energy Services, Inc. Wellbore completion design to naturally separate water and solids from oil and gas
US7429332B2 (en) 2004-06-30 2008-09-30 Halliburton Energy Services, Inc. Separating constituents of a fluid mixture
US7462274B2 (en) 2004-07-01 2008-12-09 Halliburton Energy Services, Inc. Fluid separator with smart surface
US8449750B2 (en) 2004-07-01 2013-05-28 Halliburton Energy Services, Inc. Fluid separator with smart surface
US8211284B2 (en) 2004-07-01 2012-07-03 Halliburton Energy Services, Inc. Fluid separator with smart surface
US7823635B2 (en) 2004-08-23 2010-11-02 Halliburton Energy Services, Inc. Downhole oil and water separator and method
US7828058B2 (en) 2007-03-27 2010-11-09 Schlumberger Technology Corporation Monitoring and automatic control of operating parameters for a downhole oil/water separation system
GB2459993A (en) * 2007-03-27 2009-11-18 Schlumberger Holdings Control of a downhole oil/water separation system
GB2459993B (en) * 2007-03-27 2010-11-17 Schlumberger Holdings Control of operating parameters of a downhole oil/water separation system
GB2463140B (en) * 2007-03-27 2010-12-08 Schlumberger Holdings Control of operating parameters of a downhole oil/water separation system
GB2472151A (en) * 2007-03-27 2011-01-26 Schlumberger Holdings Method of operating a downhole oil water separator
GB2463140A (en) * 2007-03-27 2010-03-10 Schlumberger Holdings A method of operating a downhole oil water separator
GB2448017A (en) * 2007-03-27 2008-10-01 Schlumberger Holdings Control of a downhole oil/water separation system
GB2448017B (en) * 2007-03-27 2010-01-06 Schlumberger Holdings Monitoring and automatic control of operating parameters for a downhole oil/water separation system
WO2011081529A1 (fr) * 2009-12-29 2011-07-07 Aker Subsea As Commande de cyclone sous-marin
GB2489139A (en) * 2009-12-29 2012-09-19 Aker Subsea As Control of subsea cyclone
RU2552538C2 (ru) * 2009-12-29 2015-06-10 Акер Сабси АС Управление расположенным под водой циклоном
GB2489139B (en) * 2009-12-29 2016-02-17 Aker Subsea As Control of subsea cyclone
NO331292B2 (no) * 2009-12-29 2016-04-22 Aker Subsea As Syklonstyring
AU2010337437B2 (en) * 2009-12-29 2016-09-29 Aker Subsea As Control of subsea cyclone
EA035659B1 (ru) * 2010-04-23 2020-07-23 Вулко С.А. Система контроля устойчивости гидроциклона
WO2011130783A1 (fr) * 2010-04-23 2011-10-27 Vulco S.A. Système de régulation de stabilité pour un hydrocyclone
EA032107B1 (ru) * 2010-04-23 2019-04-30 Вулко С.А. Система контроля устойчивости гидроциклона
US9770723B2 (en) 2010-04-23 2017-09-26 Vulco S.A. Stability control system for a hydrocyclone
US8951418B2 (en) 2010-04-23 2015-02-10 Vulco S.A. Stability control system for a hydrocyclone
US9671262B2 (en) 2012-10-31 2017-06-06 Halliburton Energy Services, Inc. Systems and methods for analyzing flowback compositions in real time
US8812238B2 (en) 2012-10-31 2014-08-19 Halliburton Energy Services, Inc. Systems and methods for analyzing flowback compositions in real time
WO2014070905A1 (fr) * 2012-10-31 2014-05-08 Halliburton Energy Services, Inc. Systèmes et procédés pour analyser des compositions d'écoulement de retour en temps réel
GB2514589A (en) * 2013-05-30 2014-12-03 Nat Oilwell Varco Lp A centrifuge
US10155230B2 (en) 2013-05-30 2018-12-18 National Oilwell Varco, L.P. Centrifuge for separating solids from solids laden drilling fluid
GB2514589B (en) * 2013-05-30 2020-01-29 Nat Oilwell Varco Lp Centrifuge for separating solids from solids laden drilling fluid
WO2025049282A1 (fr) * 2023-08-25 2025-03-06 Halliburton Energy Services, Inc. Séparateur de fluide de fond de trou dans un puits multilatéral de nouvelle entrée
WO2025049285A1 (fr) * 2023-08-25 2025-03-06 Halliburton Energy Services, Inc. Conception de séparateur de fluide de fond de trou dans un puits multilatéral

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CA2281809A1 (fr) 1998-08-27
NO994068L (no) 1999-10-19
AU6275898A (en) 1998-09-09
NO994068D0 (no) 1999-08-24

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