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WO1999047790A1 - Extraction de fluides des puits - Google Patents

Extraction de fluides des puits Download PDF

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Publication number
WO1999047790A1
WO1999047790A1 PCT/GB1999/000738 GB9900738W WO9947790A1 WO 1999047790 A1 WO1999047790 A1 WO 1999047790A1 GB 9900738 W GB9900738 W GB 9900738W WO 9947790 A1 WO9947790 A1 WO 9947790A1
Authority
WO
WIPO (PCT)
Prior art keywords
control
control circuit
hydraulic
well
electrical
Prior art date
Application number
PCT/GB1999/000738
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
Application filed by Abb Offshore Systems Limited filed Critical Abb Offshore Systems Limited
Priority to BR9908712-0A priority Critical patent/BR9908712A/pt
Priority to DE69908757T priority patent/DE69908757D1/de
Priority to AU27400/99A priority patent/AU2740099A/en
Priority to EP99907771A priority patent/EP1062405B1/fr
Publication of WO1999047790A1 publication Critical patent/WO1999047790A1/fr
Priority to NO20004549A priority patent/NO329263B1/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
    • E21B43/12—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
    • 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
    • E21B34/066—Valve arrangements for boreholes or wells in wells electrically actuated
    • 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
    • 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
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/02—Down-hole chokes or valves for variably regulating fluid flow
    • 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

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 constructed by drilling a borehole and then lining it with a steel casing which is cemented into position.
  • a conduit for carrying hydrocarbons from a lower region of the well to the surface referred to as production tubing, is inserted into the casing and extends from the surface to the lower region from where hydrocarbons are extracted.
  • the space created between the casing and the production tubing is referred to as the annulus.
  • Intake of hydrocarbons into the production tubing is either via an open lower end, one or more regions provided with ports along its length or both.
  • Devices referred to as packers are provided between the production tubing and the casing to prevent hydrocarbons flowing up the annulus rather than up the production tubing.
  • material other than hydrocarbons can flow along the production tubing. It may convey debris remaining from
  • hydrocarbons hydrocarbons
  • 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 2 in the extraction of hydrocarbons.
  • hydrocarbons An example is an annular isolation valve.
  • These flow control means are referred to as chokes.
  • chokes To locate such chokes in the well, it is convenient to provide them on the production tubing to control the flow of hydrocarbons from the exterior of the tubing into its interior.
  • Devices located in the well are referred to as downhole devices.
  • 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
  • the relative movement can be parallel to the axis of the production tubing or about it.
  • FIG. 1 An example of a known choke-controlled well 100 is shown in Figure 1.
  • the well 100
  • zone 104 may not be very thick (for
  • hydrocarbon bearing zone 106 which is in the form of
  • the zone 104 is large enough to justify the cost of drilling the well
  • the well extends in the form of a horizontal leg 108 to extract hydrocarbons from a significant extent of the zone 104.
  • hydrocarbon bearing zones are rarely
  • the leg 108 is provided with a number of chokes 110 in respective sealed regions 112 which control the intake of hydrocarbons into the leg 108.
  • the regions may not necessarily be hermetically sealed. Should water break into any sealed region, its choke can be activated so as to prevent fluid extraction from that sealed
  • the zone 106 is not large enough to justify the cost of drilling a separate well
  • the horizontal leg 108 can extend for many kilometres.
  • a similar length of horizontal well can be provided by two 4 shorter horizontal legs branching off into the zone 104 in opposite directions from a
  • the shape of the well is similar to an inverted T.
  • common junction point may be controlled by a choke.
  • Intervention costs for a well can cost in the region of $1 million per day.
  • it 5 is desirable for a well to be shut down as infrequently as possible during its lifetime.
  • a control system for controlling flow of fluid in a well comprising a first control circuit, a second
  • control circuit a downhole device and selection means, the selection means switching control of the downhole device from the first control circuit to the second control circuit, in which one of the control circuits is hydraulic and the other of the control
  • circuits is electrical.
  • the downhole device is a choke.
  • the first control circuit is wholly hydraulic.
  • the first control circuit includes a hydraulic actuator for controlling the downhole device.
  • the second control circuit is wholly electrical. Conveniently the second control circuit
  • second control circuit is electro-hydraulic. It may include a hydraulic actuator to
  • control the downhole device which is itself controlled by at least one electrical control
  • devices or individual groups of devices can be selected to operate. They may be
  • selection logic such as hydraulic addressing by the hydraulic
  • control of the downhole device is switched from the first control circuit to the second control circuit in the event of failure occurring which prevents normal operation of the downhole device by the first control circuit. Therefore the system is provided with redundancy in the event of failure.
  • switching control may simply be as a result of considerations other than failure such as a matter of choice by an operator or automated control system.
  • control module having a hydraulic actuator and an
  • control module also comprises the downhole device.
  • a well comprising at least
  • a well comprising at
  • hydraulic control circuit and the other of the control circuits is an electrical control
  • the well is a production well. It may be for producing oil, gas or both. Alternatively it may be an injection well.
  • control circuits control separate actuators which, in turn, control the downhole device.
  • control circuits control the same actuator.
  • 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 choke
  • Figure 5 shows a cross section of a flat pack control cable
  • FIG. 6 shows in schematic form a control system for a production well; 8 Figure 7 shows a hydraulic decoder;
  • Figure 8 shows a number of control modules of the control system in a ring
  • FIG. 9 shows detail of one of the control modules of Figure 8.
  • a part of the control system is located downhole and a part of the
  • control system is located on the seabed and a final part which supplies power and control signals is located on a platform or land based installation.
  • a final part which supplies power and control signals is located on a platform or land based installation.
  • invention also applies to a wholly autonomous intelligent well in which processing means are provided downhole to analyse operating parameters of the well and control its operation accordingly with little or no intervention from outside of the well.
  • Figure 2 shows a schematic illustration of a control system 220 providing control of a well 222 from a platform 224.
  • the control system 220 providing control of a well 222 from a platform 224.
  • platform is an oil rig. Located on the platform 224 is an electrical power supply unit
  • the umbilical 234 is terminated at an umbilical termination assembly 240 which
  • SCM subsea control module
  • a tree 244 also known as a Christmas tree or xmas tree, which is located on the
  • the SCM also provides the
  • any electrical or optical power/control for the downhole equipment can be sourced or routed via the SCM.
  • FIG. 3 A diagrammatic representation of a known well 10 is shown in Figure 3. This shows a bore 12 lined with a casing 14 which contains production tubing 16. The casing extends from the surface 18 until the end or toe 20 of the bore 12. It should be
  • the surface 18 is the seabed.
  • the casing 14 supports a tubing hanger 22 which in turn supports the production tubing 16.
  • casing 14 and production tubing 16 are separated by a space 24 which is referred to as
  • annulus serves a number of purposes. It can be used to detect fluid
  • pressurised gas can be introduced down the annulus and introduced into the production
  • tubing through one-way valves along its length so as to provide a gas lift and assist
  • Tubing hanger 22 accommodates a bore for the production tubing 16, a bore to allow
  • the production tubing 16 has a SCSSV (surface
  • the barrier is intentionally located below the wellhead to protect the aquatic environment in the event of a failure of the tree or wellhead.
  • the casing 14 passes through a number of hydrocarbon bearing zones 26 and 28 from which hydrocarbons such as oil and gas are extracted. Within each zone a part or region of the casing 14 is open such that hydrocarbons can flow into its
  • the production tubing 16 is likewise provided with ports
  • the production tubing may be provided with an electrical submersible
  • ESP pump
  • hydrocarbon bearing zones 32 and 34 If these zones contain aquifer layers from
  • compartments 36, 38 and 40 divided by packers 42, 44 and 46 which prevent transfer of material between hydrocarbon bearing zones 26 and 28 and non- hydrocarbon bearing zones 32 and 34 occurring along the annulus 24.
  • Hydrocarbons present in the zones 26 and 28 may be at different pressures. If the pressures are considerably different, hydrocarbons could flow from one zone to another rather than up the production tubing 16 if there is unrestricted communication between
  • variable chokes 48 and 49 are provided to restrict flow from zones 26 and 28 into the production tubing 16. Two chokes are needed to control
  • n chokes can control n zones.
  • a sensor is provided to measure
  • the senor is placed
  • hydrocarbons may be any hydrocarbon bearing zones. This is because the hydrocarbons may be any hydrocarbon bearing zones. This is because the hydrocarbons may be any hydrocarbon bearing zones. This is because the hydrocarbons may be any hydrocarbon bearing zones.
  • the senor takes its measurements through a 12 port provided in the wall of the production tubing 16.
  • Figure 4 shows a choke in greater detail. It comprises a non-perforated sleeve 410
  • the choke described in Figure 4 is a simple on/off
  • An alternative embodiment of a choke has a number of intermediate positions definable between the open and closed configurations. These positions allow a variable choking effect on the fluid flow, thus enabling a variable pressure drop to be applied.
  • Figure 4 shows a sleeve which moves in a direction parallel to the longitudinal axis of the production tubing, a sleeve which moves circumferentially
  • a flat pack is used to supply hydraulic power, electrical power and communications,
  • the flat-pack contains a hydraulic
  • All of the lines 512, 514 and 516 comprise
  • the flat pack has a 13 maximum size. Therefore there is a limitation on the number of lines and the outer
  • Figure 6 shows a control system 50 for a production well.
  • the control system 50 has
  • Each flat pack extends down the
  • the flat packs 52 and 54 are strapped to the outside of the production tubing 16 on opposite sides. In this way a damaging impact to one side of the production tubing is less likely to damage both flat packs.
  • the flat packs enable control of downhole control modules 56 and 58 incorporating
  • control modules are integrated into the production tubing 16 as individual sections to be connected in-line allowing through-flow of
  • the chokes 60 and 62 are controlled by either a hydraulic actuator 64
  • the flat packs 52 and 54 each have a hydraulic control line 72 or 74, an electrical
  • Each flat pack terminates at the top of 14 each control module and then extends onward from its bottom.
  • control module which can extract appropriate power
  • the control system has a hydraulic control circuit comprising hydraulic control lines
  • Each control circuit is capable of over-riding the other.
  • Hydraulic operation of the chokes 60 and 62 by the hydraulic control circuit is the primary control mode of the control modules 56 and 58.
  • An example of a hydraulic decoder 68 and hydraulic actuator 64 combination is shown in Figure 7. The hydraulic
  • Hydraulic control line 72 provides a standing hydraulic supply to control the
  • Hydraulic control line 74 provides a variable hydraulic supply
  • valves 80 and 82 are configured such that, in the absence of the variable
  • hydraulic supply valve 80 is closed (that is it does not transmit the standing hydraulic
  • valve 82 is open (that is it does transmit the standing hydraulic supply).
  • Naive 80 is configured to energise at lOOOpsi and valve 82 is configured to energise
  • valve 80 energises into an open state. Since valve 82 is already open, the 15 standing hydraulic supply is transmitted through the decoder 68 to provide the actuator
  • valve 64 With a control signal 88. Once the variable hydraulic supply exceeds 1200psi, valve
  • valves 84 and 86 are in a similar "one open, one closed" configuration in the
  • Valves 84 and 86 are configured to activate
  • the standing hydraulic supply is transmitted through the combination of valves 84 and 86 when the variable hydraulic supply is between 1500psi and 1700psi thus providing the actuator 64 with a control signal 90.
  • the actuator 64 receives the control signal 88 it actuates so as to open the choke.
  • the actuator 64 receives the control signal 90 it actuates so as to close the choke. Therefore opening and closing of the choke is a wholly hydraulic operation.
  • the electrical power and communications lines in the flat packs are
  • the hydraulic decoders in each control module are activated at different pressures
  • each electrical decoder 70 is provided with an
  • FIG. 6 shows the control modules 56 and 58 taking their electrical power
  • control modules are controlled by the
  • hydraulic lines 72 and 74 are needed in order to address individual hydraulic actuators.
  • control system 50 switches to the secondary control mode. If
  • a position sensor connected to a moveable part of the choke
  • such as the sliding sleeve may indicate that it is not moving in response to instructions
  • Sensors in the production tubing may indicate that there is no change in
  • Failure detection means are provided to detect failure and to
  • control selection means to switch control from the primary to the secondary control
  • the failure detection means and the selection means can conveniently be located in the electrical control unit 230 shown in Figure 2.
  • control is either exclusively hydrauhc or electrical. It does not use electro-hydraulic control in which an electrical signal controls an electrical control valve which drives a hydraulic actuator to control the choke.
  • electro-hydraulic control requires a maintained provision both of electrical and hydraulic power. Failure of either causes failure of
  • electro-hydraulic control In other embodiments of the invention, electro-
  • control modules 56 may be employed.
  • the control modules 56 may be employed.
  • the control modules 56 may be employed.
  • the control modules 56 may be employed.
  • the hydraulic switching means are configured to control the hydraulic supply by using an electrical control signal.
  • Associated with the choke assembly is a series of sensors. Typically these would be
  • the sensors are monitored and/or interrogated locally by the control module on the
  • choke and information derived is sent to the SCM. However, they may be monitored and/or interrogated remotely from the wellhead or the platform. Such remote
  • interrogation would be appropriate for sensors which are optical in nature and relay an optical signal by one or more optical fibres.
  • Other downhole devices can be operated (that is controlled, monitored or both) by the control system. Conveniently they can be integrated with the control and communication infrastructure of the control system. Examples of such downhole devices are flow meters, remotely set production packers and gas lift valves. It is necessary for regulatory purposes to have one flowmeter for
  • position sensor is also provided to detect the configuration (open or closed) of the
  • control modules which are disposed along the production tubing
  • control modules 810 are connected by flat pack 812
  • Another flat pack 816 provides a return leg
  • flat packs each comprise a hydraulic power line 872 or 874, an electrical power line
  • Figure 9 shows a schematic illustration of one of the control modules of Figure 8.
  • the flat packs 912 and 916 enter the control module 900 from above.
  • the flat packs 912 and 916 carry respective hydraulic power lines 972 and 974, electrical power lines
  • the hydraulic power lines 972 and 974 are supplied to a hydraulic decoder 968. If the
  • control module 900 is operating in primary control mode and the decoder 968 is
  • the electrical power lines 976 and a single communications line 978 are supplied to an
  • control module 900 If the control module 900 is operating in secondary control
  • a position sensor 904 is connected to the common drive means 902 to sense if the choke 960 is open or closed.
  • the control module 900 is also provided with a pressure sensor 906 and a temperature sensor 908 to measure the pressure and the temperature of the hydrocarbons flowing in the production tube.
  • Signals from all of the sensors 904, 906 and 908 are combined together at a multiplexer 909 and transmitted to the wellhead, SCM or platform by a sensor
  • One of the communications lines 978 likewise passes
  • the electrical decoder 970 provides an input to the electrical decoder 970 to enable it to determine if it is being 21 addressed. Once the electrical decoder 970 has analysed a series of control signals, it
  • control modules 810 are referred to as
  • Electrical control signals can be routed around the ring bidirectionally. As can
  • first flat pack is used to connect all of the nodes in series from a first node (which is closest to the surface) to an nth node, (which is closest to the toe of the well) and the other (second) flat pack serves as a return leg running from the nth
  • the first flat pack has a first connection made to the first node 820
  • the second flat pack has a first connection made to the first node 820
  • the third and further nodes are
  • the nodes serve as repeaters for electrical control signals. Since the communications 22 lines are arranged in a ring electrical control signals are received by an electrical
  • processor in each control module which extracts control signals specific to it and passes
  • the control modules each receive an electrical power supply provided by both flat
  • module has an arrangement of diodes to consolidate the electrical power supply and
  • the choke can be operated by two independent control circuits, one being hydraulic

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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)
  • Fluid-Pressure Circuits (AREA)
  • Earth Drilling (AREA)
  • Treatment Of Liquids With Adsorbents In General (AREA)

Abstract

L'invention concerne un système de surveillance (50) permettant de surveiller l'écoulement d'hydrocarbures hors du puits de production. Le système de surveillance présente un premier circuit de surveillance qui est entièrement hydraulique et un second circuit de surveillance qui est entièrement électrique. Les actionneurs hydraulique (66) et électrique (66) associés respectivement aux premier et second circuits de surveillance surveillent le fonctionnement de duses (60, 62) se trouvant dans le puits.
PCT/GB1999/000738 1998-03-13 1999-03-11 Extraction de fluides des puits WO1999047790A1 (fr)

Priority Applications (5)

Application Number Priority Date Filing Date Title
BR9908712-0A BR9908712A (pt) 1998-03-13 1999-03-11 Poço, sistema de controle para controlar o fluxo de fluido no mesmo, método para sua operação, circuito de controle e módulo de controle
DE69908757T DE69908757D1 (de) 1998-03-13 1999-03-11 Förderung von bohrlochflüssigkeiten
AU27400/99A AU2740099A (en) 1998-03-13 1999-03-11 Extraction of fluids from wells
EP99907771A EP1062405B1 (fr) 1998-03-13 1999-03-11 Extraction de fluides des puits
NO20004549A NO329263B1 (no) 1998-03-13 2000-09-12 System og modul for styring av bronnfluidstromning, bronn utstyrt dermed, og tilsvarende fremgangsmate

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB9805472.9 1998-03-13
GB9805472A GB2335215B (en) 1998-03-13 1998-03-13 Extraction of fluids from wells

Publications (1)

Publication Number Publication Date
WO1999047790A1 true WO1999047790A1 (fr) 1999-09-23

Family

ID=10828562

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB1999/000738 WO1999047790A1 (fr) 1998-03-13 1999-03-11 Extraction de fluides des puits

Country Status (7)

Country Link
EP (1) EP1062405B1 (fr)
AU (1) AU2740099A (fr)
BR (1) BR9908712A (fr)
DE (1) DE69908757D1 (fr)
GB (2) GB2335215B (fr)
NO (1) NO329263B1 (fr)
WO (1) WO1999047790A1 (fr)

Cited By (6)

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WO2001031167A1 (fr) * 1999-10-28 2001-05-03 Halliburton Energy Services Dispositif de regulation de flux pour puits souterrain
WO2002072999A1 (fr) * 2001-03-09 2002-09-19 Alpha Thames Ltd Raccord d'alimentation a des arbres de tete de puits et/ou commande d'arbres de tete de puits
FR2827334A1 (fr) * 2001-07-16 2003-01-17 Hydro Equipements Procede d'analyse selectif d'un fluide dans un forage et dispositif pour sa mise en oeuvre
US7306043B2 (en) 2003-10-24 2007-12-11 Schlumberger Technology Corporation System and method to control multiple tools through one control line
US9228423B2 (en) 2010-09-21 2016-01-05 Schlumberger Technology Corporation System and method for controlling flow in a wellbore
US10745998B2 (en) 2015-04-21 2020-08-18 Schlumberger Technology Corporation Multi-mode control module

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US6470970B1 (en) 1998-08-13 2002-10-29 Welldynamics Inc. Multiplier digital-hydraulic well control system and method
US6179052B1 (en) 1998-08-13 2001-01-30 Halliburton Energy Services, Inc. Digital-hydraulic well control system
US6567013B1 (en) 1998-08-13 2003-05-20 Halliburton Energy Services, Inc. Digital hydraulic well control system
US6536530B2 (en) 2000-05-04 2003-03-25 Halliburton Energy Services, Inc. Hydraulic control system for downhole tools
AU2000245031A1 (en) * 2000-05-04 2001-11-12 Halliburton Energy Services, Inc. Hydraulic control system for downhole tools
EP1283940B1 (fr) * 2000-05-22 2006-07-12 WellDynamics Inc. Debitmetre a commande hydraulique utilise dans un puits souterrain
US7182139B2 (en) * 2002-09-13 2007-02-27 Schlumberger Technology Corporation System and method for controlling downhole tools
US7013980B2 (en) 2003-08-19 2006-03-21 Welldynamics, Inc. Hydraulically actuated control system for use in a subterranean well
US7147054B2 (en) 2003-09-03 2006-12-12 Schlumberger Technology Corporation Gravel packing a well
WO2006124024A1 (fr) 2005-05-13 2006-11-23 Welldynamics, Inc. Module de commande a ligne simple pour actionner un outil de forage
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US8347967B2 (en) 2008-04-18 2013-01-08 Sclumberger Technology Corporation Subsea tree safety control system
US8157016B2 (en) 2009-02-23 2012-04-17 Halliburton Energy Services, Inc. Fluid metering device and method for well tool
US8960295B2 (en) 2009-04-24 2015-02-24 Chevron U.S.A. Inc. Fracture valve tools and related methods
WO2010124303A2 (fr) 2009-04-24 2010-10-28 Completion Technology Ltd. Procédés et systèmes destinés au traitement de puits de pétrole et de gaz
CN102031953B (zh) * 2010-12-07 2013-08-21 中国海洋石油总公司 一种智能井井下层位选择液压解码方法及装置
RU2488688C1 (ru) * 2012-02-17 2013-07-27 Общество с ограниченной ответственностью Научно-техническое предприятие "Нефтегазтехника" Насосная пакерная кабельная система для одновременно - раздельного исследования и эксплуатации многопластовой скважины (варианты)
US9267356B2 (en) * 2012-08-21 2016-02-23 Ge Oil & Gas Uk Limited Smart downhole control
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MX2016005561A (es) * 2013-11-15 2016-10-26 Landmark Graphics Corp Optimizacion de propiedades del dispositivo de control de flujo en un pozo productor en sistemas de inundacion de liquido inyector-productor acoplados.
WO2015073034A1 (fr) * 2013-11-15 2015-05-21 Landmark Graphics Corporation Optimisation des propriétés d'un dispositif de contrôle d'écoulement à la fois sur des puits de production et des puits d'injection dans des systèmes d'injection de liquide injecteur-producteur couplés
NO337678B1 (no) 2014-05-26 2016-06-06 Fmc Kongsberg Subsea As Undersjøisk effektdistribusjonsinnretning og - system.
CN111663919B (zh) * 2020-04-23 2022-07-22 中国海洋石油集团有限公司 一种油气分层开采用解码器
CN111663921B (zh) * 2020-04-23 2022-11-08 中国海洋石油集团有限公司 一种三管线控制六层位滑套的井下液压系统
AU2021377247B2 (en) 2020-11-12 2024-08-01 Moog Inc. Subsurface safety valve actuator
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WO2002072999A1 (fr) * 2001-03-09 2002-09-19 Alpha Thames Ltd Raccord d'alimentation a des arbres de tete de puits et/ou commande d'arbres de tete de puits
FR2827334A1 (fr) * 2001-07-16 2003-01-17 Hydro Equipements Procede d'analyse selectif d'un fluide dans un forage et dispositif pour sa mise en oeuvre
US7306043B2 (en) 2003-10-24 2007-12-11 Schlumberger Technology Corporation System and method to control multiple tools through one control line
US9228423B2 (en) 2010-09-21 2016-01-05 Schlumberger Technology Corporation System and method for controlling flow in a wellbore
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Also Published As

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DE69908757D1 (de) 2003-07-17
GB2335216A (en) 1999-09-15
NO20004549D0 (no) 2000-09-12
GB9823582D0 (en) 1998-12-23
AU2740099A (en) 1999-10-11
GB2335215A (en) 1999-09-15
BR9908712A (pt) 2001-10-02
NO329263B1 (no) 2010-09-20
GB2335215B (en) 2002-07-24
GB9805472D0 (en) 1998-05-13
EP1062405A1 (fr) 2000-12-27
EP1062405B1 (fr) 2003-06-11
NO20004549L (no) 2000-11-13

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