WO1999047788A1 - Gestion de puits - Google Patents

Gestion de puits Download PDF

Info

Publication number
WO1999047788A1
WO1999047788A1 PCT/GB1999/000735 GB9900735W WO9947788A1 WO 1999047788 A1 WO1999047788 A1 WO 1999047788A1 GB 9900735 W GB9900735 W GB 9900735W WO 9947788 A1 WO9947788 A1 WO 9947788A1
Authority
WO
WIPO (PCT)
Prior art keywords
control
hydraulic
well
downhole
control system
Prior art date
Application number
PCT/GB1999/000735
Other languages
English (en)
Inventor
Neil Irwin Douglas
Original Assignee
Abb Offshore Systems Limited
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
Priority claimed from GB9805472A external-priority patent/GB2335215B/en
Application filed by Abb Offshore Systems Limited filed Critical Abb Offshore Systems Limited
Priority to AU27398/99A priority Critical patent/AU2739899A/en
Publication of WO1999047788A1 publication Critical patent/WO1999047788A1/fr

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
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/02—Surface sealing or packing
    • E21B33/03—Well heads; Setting-up thereof
    • E21B33/035—Well heads; Setting-up thereof specially adapted for underwater installations
    • E21B33/0355—Control systems, e.g. hydraulic, pneumatic, electric, acoustic, for submerged well heads
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/16—Control means therefor being outside the borehole
    • 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
    • E21B43/14—Obtaining from a multiple-zone well

Definitions

  • This invention relates to controlling the flow of fluids in a well. It is particularly, but
  • An oil or gas well hereinafter referred to as a well, is typically constructed by drilling
  • conduit for carrying hydrocarbons from a lower region of the well to the surface referred to as production tubing
  • production tubing conduit for carrying hydrocarbons from a lower region of the well to the surface
  • annulus A location which is in the well is referred to as downhole.
  • packers are provided between the production tubing and the casing to prevent flow
  • hydrocarbons is
  • materials may be present. Furthermore, materials may be conveyed from the surface to the lower region, such as chemicals, including water, which are provided to assist in the extraction 2 of hydrocarbons.
  • hydrocarbons hydrocarbons.
  • An example is an annular isolation valve.
  • Such flow control means are
  • chokes generally referred to as chokes. To locate chokes downhole, it is convenient to provide
  • a simple version of a choke comprises a body provided with a set of holes carrying a
  • the body is provided with a first set of holes and the
  • sleeve is provided with a second set of holes. Relative movement of the body and sleeve
  • An alternative embodiment of a choke has a number of intermediate positions definable between the open and closed 3 configurations. These positions allow a variable choking effect on the fluid flow, thus
  • FIG. 1 An example of a known choke-controlled well 10 is shown in Figure 1.
  • the well 10 has
  • a wellhead 12 controlling a main bore 14 which extends down into a hydrocarbon
  • zone 16 may not be very thick (for example 10 to 100m)
  • hydrocarbon bearing zone 18 which is in the form of an isolated pocket.
  • zone 16 is large enough to justify the cost of drilling the well 10.
  • the well extends in the form of
  • the leg 20 is provided with a number of chokes 22 in respective sealed regions 24 which control the
  • zone comprises porous material. Should water break into any region, its choke can be
  • the zone 18 is not large
  • the horizontal leg 20 may extend for many kilometres. The 4 longer the leg is, the more uneven is fluid flow along it. Therefore, rather than having
  • a similar length of horizontal well can be provided by two shorter
  • junction point The shape of the well is similar to an inverted T.
  • a choke may be controlled by a choke.
  • hydrocarbon reserves can be extracted if the zones are allowed to recover. Furthermore,
  • Remotely controlled chokes can be used in switching extraction operations.
  • actuators of the chokes 5 receive a common hydraulic supply which is switched to operate particular chokes by
  • Intervention costs for a well can cost in the region of $1 million per day.
  • controlUng flow of fluid in a well comprising a downhole device and a control unit for
  • the hydrauUc control units receive hydraulic control signals along hydrauUc Unes extending down the weU.
  • At least one of the downhole devices is a choke. Most preferably aU are chokes. Alternatively the plurality of downhole devices are a pluraUty of sub-
  • the hydrauUc control units includes a hydraulic actuator for operating a
  • the hydraulic control unit includes a hydrauUc addressing
  • the unit which produces an actuation signal to actuate the hydrauUc actuator.
  • the actuation signal to actuate the hydrauUc actuator.
  • hydrauUc control units comprise the downhole devices.
  • a control unit for operating a downhole device the control unit producing a first actuation signal in response to a 7 hydraulic control signal having a pressure within a predetermined range the first
  • control unit comprises an actuator which operates the downhole device in response to the actuation signals.
  • control unit is configured to produce
  • the downhole device is a choke. It may be a downhole safety valve, or an
  • isolator sleeve such as a sliding sleeve. It may be a packer, a gaslift control valve, a
  • downhole devices are provided they may be of the same type or they may be of different
  • a well comprising a
  • the well is a production well. It may be for producing oil, gas or both. Alternatively it may be an injection well. 8 An embodiment of the invention will now be described by way of example only with
  • Figure 1 shows a schematic illustration of a production well
  • Figure 2 shows a schematic illustration of a control system
  • Figure 3 shows a diagrammatic representation of a production well
  • Figure 4 shows a cross section of a flat pack control cable
  • Figure 5 shows downhole details of the control system of Figure 2
  • Figure 6 shows a hydraulic decoder
  • Figure 7 shows an alternative embodiment of a hydraulic decoder.
  • suppUes power and control signals is located on a platform or land based instaUation.
  • the invention also appUes
  • FIG. 2 shows a schematic illustration of a control system 30 providing control of a
  • a hydraulic supply unit 36 Located on the platform 34 is a hydraulic supply unit 36 and a sensor
  • umbilical 42 which passes from the platform 34 to the seabed 44.
  • the umbilical 42 terminates on a tree 46, also known as a christmas tree, 9 which is located on a wellhead 48 at the seabed 44.
  • Actuators on the tree 46 open and close
  • valves which control the flow of chemicals and hydrocarbons through the tree.
  • sensor control unit 38 monitors and/or interrogates a number of sensors located on the
  • the sensors are operated either electricaUy or optically.
  • hydrauUc power unit 36 controls and operates several downhole devices located in the
  • FIG. 3 A diagrammatic representation of a known well 10 is shown in Figure 3. This shows a bore 54 Uned with a casing 56 which contains production tubing 58.
  • annulus 66 The annulus
  • valves along its length so as to provide a gas lift and assist extraction.
  • the tubing hanger 54 accommodates a bore for the production tubing 58, a bore to allow
  • the production tubing 58 has a SCSSN (surface
  • the barrier is
  • each zone a part or region of the casing 56 is open such that hydrocarbons can flow into its interior.
  • the wall of the casing 56 is perforated.
  • the casing has an open end 74.
  • the production tubing 58 is likewise provided with ports which correspond to those present in the casing 56. Therefore the production tubing 58 has
  • the production tubing may be provided with a motor driven electrical
  • annulus 66 is divided into
  • Hydrocarbons present in the zones 70 and 72 may be at different pressures. If the
  • variable chokes 90 and 92 are provided to restrict flow from
  • zones 70 and 72 into the production tubing 58 Two chokes are needed to control extraction of hydrocarbons from two zones.
  • n chokes are used to control n
  • sensors are provided to measure
  • a flat pack is used to supply hydrauUc power to downhole devices and electrical
  • a cross-section of a flat pack is
  • the flat-pack contains a hydrauUc
  • All of the Unes 96, 98 and 100 comprise steel jackets or 12 tubes. Due to space constraints within the tubing hanger 54, and in the annulus 66, the
  • FIG. 5 shows downhole detatts of the control system of Figure 2. The part of the
  • control system shown, indicated by numeral 106 is being used to control a production
  • the control system 106 has two flat packs 108 and 110 which extend down the
  • annulus 66 The use of two flat packs provides redundancy within the system.
  • Each flat pack extends
  • the flat packs 108 and 110 are strapped to the outside of the production tubing 58 on opposite sides. In this way a damaging impact to one side of the production
  • tubing is less likely to damage both flat packs.
  • a single flat pack containing two hydraulic lines may be provided or even two separate
  • the flat packs enable control of downhole control modules 112 and 114 incorporating,
  • decoders 124 and 126 are integrated into
  • the chokes 116 and 118 are operated, or actuated, by hydraulic
  • actuators 120 and 122 which are controlled by respective hydraulic decoders 124 and 126.
  • the actuators may each simply comprise a hydraulic driven piston or a hydraulic 13 ram. They are each coupled to the moving section of the chokes 116 and 118.
  • the flat packs 108 and 110 each have a hydraulic control line 128, a hydraulic power
  • Each flat pack terminates at the top of each
  • control module which can extract appropriate hydrauUc
  • the control system has a hydraulic control circuit comprising hydraulic control lines
  • the hydrauUc control Unes 128 are consoUdated by a shuttle valve 134 into a single hydraulic control supply 136. This is fed into respective pairs of valves
  • the hydraulic control supply 136 provides a variable
  • valves 138, 140, 142 and 144 The valves
  • valves 138, 140, 142 and 144 are switchable through the valves 138, 140, 142 and 144 to actuate the hydraulic actuator
  • valves 138 and 140 are
  • valve 138 is closed (that is it does not transmit the hydraulic power supply 148) and valve 140 14 is open (that is it does transmit the hydraulic power supply 148).
  • Valve 138 is
  • valve 140 is configured to energise at 1200psi.
  • valve 138 energises into an open state. Since valve 140 is already open, the
  • hydraulic power supply 148 is transmitted through the decoder 124 and actuates the
  • valve 140 energises into a closed state which prevents transmission of the
  • valves 138 and 140 and 142 and 144 could be incorporated into a single valve
  • valves 142 and 144 are in a similar "one open, one closed" configuration in the
  • Valves 142 and 144 are configured to
  • Opening and closing of the choke is a whoUy
  • Each decoder receives a hydraulic control supply and
  • valves 152 and 154 That is, hydraulic power transmitted through the valves 138 and
  • a significant feature ofthe present invention is that the actuator is actuated by separate
  • each downhole control module is activated at different pressures appUed by the variable hydraulic supply. Therefore a number of downhole control modules can be selectively operated by applying an appropriate hydrauUc
  • the control system may be provided with means to detect failure. Detecting loss of
  • hydrauUc power in one of the lines may indicate a break.
  • a moveable part of the choke such as the sliding sleeve may indicate that it is not
  • Sensors in the production tubing may indicate that there is no change in pressure or flow rate or both in response to a 17 command being given for the choke to change its configuration.
  • Associated with the choke assembly is a series of sensors. Typically these would be
  • the sensors are monitored and/or interrogated locally by the downhole control module and information derived used to operate the choke or they are monitored and/or interrogated remotely from the wellhead or the platform. Such remote interrogation
  • control system such as flow meters, remotely set
  • the configuration of the choke can be
  • control modules and a plurality of chokes in an alternative embodiment only a single
  • downhole control module and a single downhole device may be provided. This may be particularly suitable for controlling a downhole device having a number of states or 18 configurations it can occupy.
  • the downhole device may comprise a number
  • sub-assemblies such as a plurality of valves each of which is switchable between two

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)
  • Fluid-Pressure Circuits (AREA)

Abstract

L'invention concerne un système de gestion (106) destiné à gérer l'écoulement d'hydrocarbures sortant d'un puits de production. Le système de gestion comprend des décodeurs hydrauliques actionnant une pluralité d'obturateurs (116 et 118). Les décodeurs hydrauliques (124 et 126) fournissent des signaux d'actionnement lors de la réception des pressions de commande hydraulique dans des gammes prédéterminées. Les signaux d'actionnement commandent un actionneur hydraulique (120 et 122) afin d'ouvrir et de fermer un obturateur particulier. Ainsi, les obturateurs peuvent être actionnés indépendamment.
PCT/GB1999/000735 1998-03-13 1999-03-11 Gestion de puits WO1999047788A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU27398/99A AU2739899A (en) 1998-03-13 1999-03-11 Well control

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
GB9805472A GB2335215B (en) 1998-03-13 1998-03-13 Extraction of fluids from wells
GB9805472.9 1998-03-13
GB9823582A GB2335216A (en) 1998-03-13 1998-10-29 Extraction of fluid from wells
GB9823582.3 1998-10-29

Publications (1)

Publication Number Publication Date
WO1999047788A1 true WO1999047788A1 (fr) 1999-09-23

Family

ID=26313285

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB1999/000735 WO1999047788A1 (fr) 1998-03-13 1999-03-11 Gestion de puits

Country Status (2)

Country Link
AU (1) AU2739899A (fr)
WO (1) WO1999047788A1 (fr)

Cited By (18)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2001083939A1 (fr) * 2000-05-04 2001-11-08 Halliburton Energy Services, Inc. Systeme de commande hydraulique pour des outils de fond de puits
US6470970B1 (en) 1998-08-13 2002-10-29 Welldynamics Inc. Multiplier digital-hydraulic well control system and method
US6536530B2 (en) 2000-05-04 2003-03-25 Halliburton Energy Services, Inc. Hydraulic control system for downhole tools
FR2831597A1 (fr) * 2001-10-30 2003-05-02 Geoservices Dispositif de completion d'une installation d'exploitation de fluides souterrains
US6567013B1 (en) 1998-08-13 2003-05-20 Halliburton Energy Services, Inc. Digital hydraulic well control system
US6575237B2 (en) 1998-08-13 2003-06-10 Welldynamics, Inc. Hydraulic well control system
GB2401888A (en) * 2003-05-01 2004-11-24 Cooper Cameron Corp Subsea electro/hydraulic choke control system
GB2410963A (en) * 2004-01-09 2005-08-17 Master Flo Valve Inc A choke system having a linear hydraulic stepping actuator
GB2411677A (en) * 2002-09-13 2005-09-07 Schlumberger Holdings Integrated control of multiple well tools
US7147054B2 (en) 2003-09-03 2006-12-12 Schlumberger Technology Corporation Gravel packing a well
GB2434166A (en) * 2006-01-13 2007-07-18 Schlumberger Holdings Electro-hydraulic control of variable choke valves in a multi-zone well
WO2008045381A3 (fr) * 2006-10-04 2008-08-07 Fluor Tech Corp Duse de production sous-marine double pour une production de puits haute pression
WO2009136950A1 (fr) * 2008-05-09 2009-11-12 Fmc Technologies Inc. Procédé et appareil pour contrôle d'état d'arbre de noël
US7845404B2 (en) 2008-09-04 2010-12-07 Fmc Technologies, Inc. Optical sensing system for wellhead equipment
AT511993A1 (de) * 2011-09-21 2013-04-15 Austrian Ct Of Competence In Mechatronics Gmbh Hydraulischer verstärker
EP2865844A3 (fr) * 2013-10-23 2016-08-10 ConocoPhillips Company Système de commande d'écoulement de la zone de fond de trou
RU2650983C2 (ru) * 2011-12-15 2018-04-20 Рейз Продакшн, Инк. Горизонтально-вертикальная насосная система для извлечения скважинной текучей среды
US9988866B2 (en) 2014-12-12 2018-06-05 Halliburton Energy Services, Inc. Automatic choke optimization and selection for managed pressure drilling

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3986554A (en) * 1975-05-21 1976-10-19 Schlumberger Technology Corporation Pressure controlled reversing valve
US3993100A (en) * 1974-04-29 1976-11-23 Stewart & Stevenson Oiltools, Inc. Hydraulic control system for controlling a plurality of underwater devices
US4549578A (en) * 1984-03-21 1985-10-29 Exxon Production Research Co. Coded fluid control system
WO1997047852A1 (fr) * 1996-06-13 1997-12-18 Pes, Inc. Vanne de lubrificateur de fond

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3993100A (en) * 1974-04-29 1976-11-23 Stewart & Stevenson Oiltools, Inc. Hydraulic control system for controlling a plurality of underwater devices
US3986554A (en) * 1975-05-21 1976-10-19 Schlumberger Technology Corporation Pressure controlled reversing valve
US4549578A (en) * 1984-03-21 1985-10-29 Exxon Production Research Co. Coded fluid control system
WO1997047852A1 (fr) * 1996-06-13 1997-12-18 Pes, Inc. Vanne de lubrificateur de fond

Cited By (37)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6567013B1 (en) 1998-08-13 2003-05-20 Halliburton Energy Services, Inc. Digital hydraulic well control system
US6470970B1 (en) 1998-08-13 2002-10-29 Welldynamics Inc. Multiplier digital-hydraulic well control system and method
US6575237B2 (en) 1998-08-13 2003-06-10 Welldynamics, Inc. Hydraulic well control system
US7145471B2 (en) 2000-02-22 2006-12-05 Welldynamics, Inc. Sequential hydraulic control system for use in a subterranean well
US6536530B2 (en) 2000-05-04 2003-03-25 Halliburton Energy Services, Inc. Hydraulic control system for downhole tools
GB2366818B (en) * 2000-05-04 2004-12-01 Halliburton Energy Serv Inc Hydraulic control system for downhole tools
WO2001083939A1 (fr) * 2000-05-04 2001-11-08 Halliburton Energy Services, Inc. Systeme de commande hydraulique pour des outils de fond de puits
GB2366818A (en) * 2000-05-04 2002-03-20 Halliburton Energy Serv Inc Hydraulic control system for downhole tools
WO2003038234A1 (fr) * 2001-10-30 2003-05-08 Geoservices Dispositif de completion d'une installation d'exploitation de fluides souterrains
FR2831597A1 (fr) * 2001-10-30 2003-05-02 Geoservices Dispositif de completion d'une installation d'exploitation de fluides souterrains
GB2411677B (en) * 2002-09-13 2006-11-29 Schlumberger Holdings System and method for controlling downhole tools
US7182139B2 (en) 2002-09-13 2007-02-27 Schlumberger Technology Corporation System and method for controlling downhole tools
GB2411677A (en) * 2002-09-13 2005-09-07 Schlumberger Holdings Integrated control of multiple well tools
GB2401888A (en) * 2003-05-01 2004-11-24 Cooper Cameron Corp Subsea electro/hydraulic choke control system
US6988554B2 (en) 2003-05-01 2006-01-24 Cooper Cameron Corporation Subsea choke control system
GB2401888B (en) * 2003-05-01 2007-02-07 Cooper Cameron Corp Subsea choke control system
US7147054B2 (en) 2003-09-03 2006-12-12 Schlumberger Technology Corporation Gravel packing a well
US7237472B2 (en) 2004-01-09 2007-07-03 Master Flo Valve, Inc. Linear hydraulic stepping actuator with fast close capabilities
GB2410963A (en) * 2004-01-09 2005-08-17 Master Flo Valve Inc A choke system having a linear hydraulic stepping actuator
GB2434166A (en) * 2006-01-13 2007-07-18 Schlumberger Holdings Electro-hydraulic control of variable choke valves in a multi-zone well
US7464761B2 (en) 2006-01-13 2008-12-16 Schlumberger Technology Corporation Flow control system for use in a well
GB2434166B (en) * 2006-01-13 2009-05-06 Schlumberger Holdings Flow control system for use in a well
NO340045B1 (no) * 2006-01-13 2017-03-06 Schlumberger Technology Bv Strømningsstyresystem for bruk i en brønn
AU2007307019B2 (en) * 2006-10-04 2013-03-07 Fluor Technologies Corporation Dual subsea production chokes for high pressure well production
WO2008045381A3 (fr) * 2006-10-04 2008-08-07 Fluor Tech Corp Duse de production sous-marine double pour une production de puits haute pression
US9051818B2 (en) 2006-10-04 2015-06-09 Fluor Technologies Corporation Dual subsea production chokes for HPHT well production
EA014623B1 (ru) * 2006-10-04 2010-12-30 Флуор Текнолоджиз Корпорейшн Двойные подводные фонтанные штуцеры для добычи в скважине высокого давления
GB2472714A (en) * 2008-05-09 2011-02-16 Fmc Technologies Method and apparatus for Christmas tree condition monitoring
GB2472714B (en) * 2008-05-09 2012-07-25 Fmc Technologies Method and apparatus for Christmas tree condition monitoring
US7967066B2 (en) 2008-05-09 2011-06-28 Fmc Technologies, Inc. Method and apparatus for Christmas tree condition monitoring
WO2009136950A1 (fr) * 2008-05-09 2009-11-12 Fmc Technologies Inc. Procédé et appareil pour contrôle d'état d'arbre de noël
US7845404B2 (en) 2008-09-04 2010-12-07 Fmc Technologies, Inc. Optical sensing system for wellhead equipment
AT511993A1 (de) * 2011-09-21 2013-04-15 Austrian Ct Of Competence In Mechatronics Gmbh Hydraulischer verstärker
AT511993B1 (de) * 2011-09-21 2014-04-15 Austrian Ct Of Competence In Mechatronics Gmbh Hydraulischer verstärker
RU2650983C2 (ru) * 2011-12-15 2018-04-20 Рейз Продакшн, Инк. Горизонтально-вертикальная насосная система для извлечения скважинной текучей среды
EP2865844A3 (fr) * 2013-10-23 2016-08-10 ConocoPhillips Company Système de commande d'écoulement de la zone de fond de trou
US9988866B2 (en) 2014-12-12 2018-06-05 Halliburton Energy Services, Inc. Automatic choke optimization and selection for managed pressure drilling

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