Patent Publication Number: US-7900705-B2

Title: Flow control assembly having a fixed flow control device and an adjustable flow control device

Description:
CROSS-REFERENCE TO RELATED APPLICATIONS 
     This claims the benefit under 35 U.S.C. §119(e) of U.S. Provisional Application Ser. No. 60/894,495, entitled “Method and Apparatus for an Active Integrated Well Construction and Completion System for Maximum Reservoir Contact and Hydrocarbon Recovery,” filed Mar. 13, 2007; and of U.S. Provisional Application Ser. No. 60/895,555, entitled, “Method and Apparatus for an Active Integrated Well Construction and Completion System for Maximum Reservoir Contact and Hydrocarbon Recovery,” filed Mar. 19, 2007, both hereby incorporated by reference. 
    
    
     TECHNICAL FIELD 
     The invention relates generally to controlling fluid flow in one or more zones of a well using a flow control assembly having a fixed flow control device and an adjustable flow control device. 
     BACKGROUND 
     A completion system is installed in a well to produce hydrocarbons (or other types of fluids) from reservoir(s) adjacent the well, or to inject fluids into the reservoirs) through the well. Typically, one or more flow control devices are provided to control flow in one or more zones of the well. 
     In a complex completion system, such as a completion system installed in a well that have many zones, many adjustable flow control devices may have to be deployed. An adjustable flow control device is a flow control device that can be actuated between different settings to provide different amounts of flow. However, adjustable flow control devices can be relatively expensive, and having to deploy a relatively large number of such adjustable flow control devices can increase costs. 
     SUMMARY 
     In general, according to an embodiment, a flow control assembly to control fluid flow in a zone of the well includes at least a fixed flow control device and an adjustable flow control device that cooperate to control the fluid flow in the zone. 
     Other or alternative features will become apparent from the following description, from the drawings, and from the claims. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         FIGS. 1-4  illustrate different embodiments of completion systems that can be deployed in a wellbore. 
         FIGS. 5A-13  illustrate different types of flow control valves, according to some embodiments. 
         FIGS. 14-22  illustrate various stages of providing completion equipment in a multilateral well, according to an embodiment. 
         FIGS. 23-25  illustrate stages of providing completion equipment in a multilateral well, according to another embodiment. 
         FIGS. 26-27  illustrate different schemes for power and data communications, according to some embodiments. 
         FIGS. 28 and 29  illustrate different electro-hydraulic wet connection mechanisms, according to some embodiments. 
     
    
    
     DETAILED DESCRIPTION 
     In the following description, numerous details are set forth to provide an understanding of the present invention. However, it will be understood by those skilled in the art that the present invention may be practiced without these details and that numerous variations or modifications from the described embodiments are possible. 
     As used here, the terms “above” and “below”; “up” and “down”; “upper” and “lower”; “upwardly” and “downwardly”; and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments of the invention. However, when applied to equipment and methods for use in wells that are deviated or horizontal, such terms may refer to a left to right, right to left, or diagonal relationship as appropriate. 
       FIG. 1  illustrates an example completion system that is deployed in a well  100 . As depicted in  FIG. 1 , several zones  102  and  104  are defined in the well  100  by isolation packers  106 ,  10 S, and  110 . The isolation packers  106 ,  108 , and  110  can be swellable packers that swell in the downhole environment, or alternatively, the isolation packers can be compression-based packers that are set by application of hydraulic pressure, for example. 
     Each zone  102 ,  104  includes a flow control assembly  112 ,  114 , respectively. The flow control assembly  112  includes a screen, such as a wire-wrapped screen  116 , which can be used to perform sand control or control of other particulates (to prevent such particulates from flowing into an inner conduit of the flow control assembly  112 ). Inside the screen  116  is a mandrel  118  on which various flow control devices are arranged, including fixed flow control devices  120 ,  122 , and  124 , and an adjustable flow control device  126 . The need for using a screen or not using a screen depends on the type of formation. Typically soft formation such as sand stone requires running a screen for preventing sand or solids production. A hard formation such as carbonate may not require a screen. However, sometime a screen is run in carbonate to prevent solids from plugging the flow control valves. A “fixed” flow control device is a flow control device whose flow path cannot be adjusted after being installed in the well. Examples of a fixed flow control device include an orifice, a tortuous flow path, or any other device that provides a pressure drop. An “adjustable flow control device” is a flow control device whose path can be adjusted after being installed in the well to different settings, including a closed setting (in which no fluid flow is allowed through the adjustable flow control device), a fully open setting (in which the flow path is at its maximum to allow maximum fluid flow through the adjustable flow control device), and one or more intermediate settings (to provide different amounts of flow across the adjustable flow control device). 
     In one example implementation, the flow control devices  120 ,  122 ,  124 , and  126  are considered inflow control devices that control the incoming flow from surrounding reservoir through the flow control devices into an inner bore  130  of the completion system depicted in  FIG. 1 . However, in a different implementation, the flow control devices can control outflow of fluid from the inner bore  130  into the surrounding reservoir (such as in the injection context). 
     In the inflow direction, fluid flows from the reservoir into a well annular region  111  outside the screen  116 , and then through the screen  116  to an annular region  113  between the screen  116  and the mandrel  118 . The fluid flow then continues through the flow control devices  120 - 126  and into the inner bore  130  for flow toward an earth surface, such as through a tubing  150 . 
     In the example depicted in  FIG. 1 , the adjustable flow control device  126  is electrically coupled through a connection sub  132  to an electrical cable  134 , which can extend from the earth surface. The electrical cable  134  runs through the isolation packer  106  and also through the isolation packer  108 . Instead of using the electrical cable  134 , a fiber optic cable or other power and telemetry mechanisms can be used. 
     The flow control assembly  114  for the second zone  104  similarly includes a screen  136 , as well as a mandrel  138  on which are mounted fixed flow control devices  140 ,  142 , and  144 , as well as an adjustable flow control device  146  that is electrically coupled through a connection sub  148  to the electrical cable  134 . 
     As depicted in  FIG. 1 , the section of the completion system that includes the two flow control assemblies  112  and  114  is positioned in a deviated or horizontal section of the well  100 . Alternatively, the section of the completion system can also be deployed in a lateral branch of a multilateral well. In a different implementation, the completion system section can be provided in a vertical section of the well  100 . 
     Although just two zones are depicted in  FIG. 1 , it is noted that additional zones of the well can be defined with the completion system in other implementations, with additional flow control assemblies similar to flow control assemblies  112  and  114  provided to control flow in these other zones. By using the completion system according to some embodiments, a particular reservoir can be compartmentalized into separate zones, where each zone is isolated from the other by isolation packers. A flow control assembly is provided in each zone to provide for independent control of fluid flow in each zone. 
     Within each zone, the flow control devices of the flow control assembly are provided to achieve a desired pressure drop from the reservoir into the inner bore  130  of the completion system. Different pressure drops can be set in different zones so that a target pressure profile can be achieved along the length of the completion system. Controlling the production profile by controlling pressure drops along the completion system in different zones has several benefits, including the reduction or avoidance of water or gas coning or other adverse effects. Water or gas coning refers to the production of unwanted water or gas prematurely, which can occur at the “heel” of the well (the zone nearer the earth surface) before zones near the “toe” of the well (the zones farther away from the earth surface). Production of unwanted water or gas in any of the zones may require special intervention that can be expensive. 
     By using the combination of fixed flow control device(s) and adjustable flow control device(s) that cooperate to provide the target flow control in each zone, costs can be reduced. Fixed flow control devices are relatively cheap to provide, as compared to adjustable flow control devices, which are higher cost devices. 
       FIG. 2  shows an alternative embodiment of a completion system that defines multiple zones  102 ,  104  in a section of a well  100 . Different embodiments of flow control assemblies  112 A and  114 A are provided in the respective zones  102  and  104 . The flow control assembly  112 A includes the screen  116 , as well as the mandrel  118  on which fixed flow control devices  120 ,  122 , and  124  are mounted. However, in the embodiment of  FIG. 2 , the adjustable flow control device  126  is provided on an inner pipe  200  that is concentrically provided inside the mandrel  118 . An annular space  202  is defined between the mandrel  118  and the pipe  200 . This arrangement of the flow control device  126  is contrasted with the flow control device  126  arranged on the mandrel  118  in  FIG. 1 . 
     Also, in  FIG. 2 , sealing elements  204  are provided inside the screen  116  such that multiple annular spaces  206 ,  208 , and  210  are defined inside the screen  116 . Fluid flows through the screen  116  into the annular spaces  206 ,  208 ,  210 , and then through corresponding fixed flow control devices  120 ,  122 , and  124  into the annular space  202  between the mandrel  118  and the pipe  200 . The fluid flows through the adjustable flow control device  126  into an inner bore  130 A of the pipe  200  for production to the earth surface. 
     The flow control assembly  114 A similarly includes the outer screen  136  and the inner mandrel  138 . Also, the pipe  200  is concentrically defined inside the mandrel  138  such that an annular space  212  is defined between the pipe  200  and the mandrel  138 . Also, sealing elements  214  are provided inside the screen  136  to define annular spaces  216 ,  218 , and  220  between the screen  136  and the mandrel  138 . Fluid flows from the reservoir through the screen  136 , annular spaces  216 ,  218 , and  220 , and through respective fixed flow control devices  140 ,  142 , and  144  on the mandrel  138  into the annular space  212  between the mandrel  138  and the pipe  200 . The fluid then flows through the adjustable flow control device  146  that is mounted on the pipe  200  to allow fluid flow into the inner bore  130 A of the pipe  200 . 
     Note that the annular spaces  202  and  212  between mandrels  118 ,  138 , and the pipe  200  are defined by sealing elements  224 ,  226 , and  227 . 
     In the embodiment of  FIG. 2 , the cable  134  extends through a sub  222  attached to the isolation packer  106 , through the sealing element  224  and into the annular space  202  between the mandrel  118  and the pipe  200 . Inside the annular space  202 , the cable  134  is electrically connected to the adjustable flow control device  126 . The cable  134  further extends through the sealing element  226  into the annular space  212 , where the cable  134  is electrically connected to the adjustable flow control device  146 . 
     The lower section of the completion system including the isolation packers  106 ,  108 ,  110  and the flow control assemblies  112 A,  114 A are connected to an upper completion section that includes tubing  150  and production packer  230 . In some implementations, the upper and lower sections can be run into the well  100  in a single trip. In a different implementation, the lower completion section can be run into the well  100  first, followed later by run-in of the upper completion section for engagement with the lower completion section. 
     The types of adjustable flow control devices that can be used in various embodiments includes sliding sleeve valves, cartridge-type valves, inflatable valves, ball valves, and so forth. In  FIGS. 1 and 2 , the actuation technique is an electric-based actuation technique, in which signals provided over the electrical cable  134  are used to actuate the adjustable flow control devices. In different embodiments, other actuation techniques can be used, including hydraulic actuation, electro-hydraulic actuation, smart fluid actuation, shaped memory alloy actuation, and electromagnetic actuation. Smart fluid actuation refers to a fluid that expands in response to electromagnetic activation. Shaped memory alloy actuation refers to the use of a shaped memory material to perform actuation. 
     In addition to flow control devices, other components can also be deployed in a completion system, according to some embodiments. For example, sensors can also be provided, such as pressure sensors, temperature sensors, flow rate sensors, fluid identification sensors, flow control valve position detection sensors, density detection sensors, chemical detection sensors, pH detection sensors, viscosity detection sensors, acoustic sensors, and so forth. 
     Communication between sensors and/or flow control devices can be accomplished using electrical signaling, hydraulic signaling, fiber optic signaling, wireless signaling, or any combination of the above. Power can be provided to electrical devices, such as sensors and adjustable flow control devices, from the earth surface, from a downhole generator, from a charge storage device such as a capacitor or battery, from activation of an explosive or other ballistic device, from chemical activation, or any combination of the above. 
       FIG. 3  shows another embodiment of a completion system in which flow control assemblies are provided.  FIG. 3  shows four isolated zones  302 ,  304 ,  306 , and  308  as defined by isolation packers  310 ,  312 ,  314 ,  316 , and  318 . Four flow control assemblies  320 ,  322 ,  324 , and  326  are provided in the respective zones  302 ,  304 ,  306 , and  308 . Each flow control assembly includes an adjustable flow control device, including an adjustable flow control device  328  in the flow control assembly  320 , an adjustable flow control device  330  in the flow control assembly  322 , an adjustable flow control assembly  332  in the flow control assembly  324 , and an adjustable flow control device  334  in the flow control assembly  326 . 
     The flow control assembly  320  includes a screen  336  through which fluid can flow into a first annular space  338  of the flow control assembly  320  between the screen  336  and mandrel  346 . The adjustable flow control device  328  is positioned between the first annular space  338  and a second annular space  340  of the flow control assembly  320  between an outer housing member  329  and the mandrel  346 . The flow control device  328  has a flow path  342  to allow for fluid communication between the annular spaces  338  and  340 . The adjustable flow control device  328  is positioned between the screen  320  and the inner mandrel  346 . In addition, a fixed flow control device  344  is defined on the inner mandrel  346 . The fixed flow control device  344  allows for fluid to flow from the second annular space  340  to an inner bore  370  of the completion system. 
     The adjustable flow control device  328  is controllable by an electrical cable  348 . Signaling provided over the electric cable  348  can be used to control the setting of the adjustable flow control device  328 . 
     The other flow control assemblies  322 ,  324 , and  326  can have identical arrangements as the flow control assembly  320 . 
     Additionally, in the zone  306 , sensors  350 ,  352 , and  354  are provided in an annulus region  356  outside a screen  358  of the flow control assembly  324 . In some implementations, the sensors  350 ,  352 , and  354  can be part of the cable  348 , thereby making the cable  348  a sensor cable that can have other sensors. A sensor cable (also referred to a “sensor bridle”) is basically a continuous control line having portions in which sensors are provided. The sensor cable is continuous in the sense that the sensor cable provides a continuous seal against fluids, such as wellbore fluids, along its length. Note that in some embodiments, the continuous sensor cable can actually have discrete housing sections that are sealably attached together (e.g., welded). In other embodiments, the sensor cable can be implemented with an integrated, continuous housing without breaks. 
     In one example implementation, the sensors  350  and  352  can be pressure sensors, with sensor  352  detecting pressure P 1  in the annulus region  356  outside the screen  358  and the sensor  350  sensing pressure P 2  in an annular space  360  downstream of the adjustable flow control device  332  between the screen  358  and an inner mandrel  362  of the flow control assembly  324 . Using the sensors  350  and  352 , the pressure difference between the annulus region  356  and the outlet of the adjustable flow control device  332  can be determined. 
     The third sensor  354  can be a fluid identification sensor to detect the type of fluid that is in the annulus region  356 . Other or alternative sensors can be provided, such as temperature sensors or other types of sensors. 
       FIG. 4  shows yet another embodiment of a completion system that can be provided in a section of a well. In the embodiment of  FIG. 4 , three zones  400 ,  402 , and  404  are defined by isolation packers  406 ,  408 ,  410 , and  412 . 
     Flow control assemblies  414 ,  416 , and  418  are provided in corresponding zones  400 ,  402 , and  404 . In the zone  400 , an adjustable flow control device  420  is mounted on an inner mandrel  422  of the flow control assembly  414 . The flow control assembly  414  also includes a screen  424  through which fluid can flow into an annulus space  426  defined between sealing elements  428  and  408 . Fluid flowing into the annulus space  426  flows out of the flow control device  420  into an inner bore  432  of the completion system. 
     The flow control assembly  416  is similarly arranged as the flow control assembly  414 , and includes an adjustable flow control device  427 . The flow control assembly  418  has two adjustable flow control devices  434  and  436  mounted on an inner mandrel  438  to control flow into the inner bore  432  of the completion system. The flow control assembly  418  also includes annular spaces  444  and  446  defined between sealing elements  448 ,  450 , and the isolation packer  412 . 
     The adjustable flow control devices  420 ,  427 ,  434 , and  436  are controlled by signaling over an electrical cable  440 . The adjustable flow control devices can be one or more of the following types of flow control devices: sliding sleeve type, cartridge type, inflatable type, and ball type. 
     Various designs of adjustable flow control devices are discussed below.  FIGS. 5A and 5B  show a first embodiment of a variable electric flow control valve  500 . The valve  500  can be mounted on a mandrel  502 , such as the inner mandrels of the various flow control assemblies discussed above. A screen  504  is provided at an inlet to the valve  500  to provide fluid flow into a space  506  inside the screen  504  at the inlet of the valve  500 . The fluid follows inlet path  508  into an inner chamber  510  defined in housing  512  of the flow control valve. The chamber  510  also contains an electric motor  514  that is configured to move a choke member  516  along a longitudinal direction of the flow control valve, indicated by axis x in  FIG. 5 . The choke member  516  has a sloped engagement surface  518  that is provided to engage corresponding sloped surface  520  in the inner wall of the housing  512 . When the sloped surfaces  518  and  520  engage, as depicted in  FIG. 5B , a sealing engagement is provided such that flow is stopped through an outlet part  522  of the flow control valve  500 . 
     The flow control valve  500  is in the choked position in  FIG. 5A  to allow fluid flow arriving at the inlet path  508  to continue through the outlet path  522  and the outlet port  524  to an inner bore of the mandrel  502 . 
     In the closed position, as shown in  FIG. 5B , the choke member  516  is engaged against the inner surface  520  of the housing  512  to prevent flow from reaching the outlet path  522 . 
     The choke member  516  is attached to an actuating rod  526  that is movable by the electric motor  514  in the longitudinal direction (x direction) to cause movement of the choke member  518 . 
     A top view of the flow control valve  500  and the mandrel  502  to which the flow control valve  500  is attached is depicted in  FIG. 6 . The flow control valve  500  allows for fluid to be communicated through the outlet port  524  of the mandrel  502  into an inner bore  600  of the mandrel  502 . 
     Note that the flow control valve  500  is positioned in a side pocket  602  defined in the outer surface of the mandrel  502 . The side pocket runs along a longitudinal direction of the mandrel  502  to allow for the valve  500  to be positioned in the side pocket  602 . In the example implementation shown in  FIG. 6 , the side pocket  602  depicted does not have a cover such that the flow control valve is exposed to the wellbore environment. In another implementation, a cover can be provided to cover the side pocket  602 . 
       FIGS. 5A-5B  also show pressure sensors P 1  and P 2  of the flow control valve  500 , with sensor P 1  used to measure pressure in the chamber  510 , and sensor P 2  used to measure pressure in the outlet path  522 . The measurement data provided by sensors P 1  and P 2  allows a well operator to determine a position of the flow control valve  500 . 
       FIG. 7  shows another electric flow control valve  700  that does not use a screen (e.g., screen  504  in  FIG. 5A ). The flow control valve  700  can also be positioned in the side pocket  602  of the mandrel  502  ( FIG. 6 ). The flow control valve  700  has an outer housing  702  with ports  704  to allow fluid to flow from outside the flow control valve  700  into a space  706  inside the housing  702  (provided a seal member  712  does not block all ports  704 ). The fluid flows through the space  706  and out along outlet path  708  to an outlet port  710  of the flow control valve  700  to allow flow into the inner bore  600  of the mandrel  502 . 
     The seal member  712  is provided inside the housing  702 , where the seal member is attached to an actuating rod  714  that is moveable by an electric motor  716 . The electric motor  716  is able to move the sealing member  712  in the longitudinal direction (of the valve  700 ) to engage an end portion  718  of the sealing member  712  against an end wall  720  inside the housing  718 . Once the sealing member  712  and end wall  720  are engaged, seals  722  (e.g., O-ring seals) on the sealing member  712  block fluid flow from entering into chamber  706 , since the sealing member  712  completely blocks all ports  704  of the housing  702 . 
     The flow control valve  700  in  FIG. 7  is depicted to be in its full open position. When the sealing member  712  is actuated to engage the end wall  720 , a fully closed position is provided. The sealing member  712  can also be provided at an intermediate position to selectively block one or more of the ports  704  to provide intermediate choke positions. 
       FIG. 8  shows a modified form of the flow control valve of  FIG. 7 , where the flow control valve of  FIG. 8  is referenced as  700 A. The difference between the flow control valve  700 A and the flow control valve  700  is the provision of a screen  800  in the  FIG. 8  embodiment. Otherwise, the flow control valve  700 A of  FIG. 8  is identical to the flow control valve  700  of  FIG. 7 . 
     A top view of the flow control valve  700 A along section  9 - 9  of  FIG. 8  is depicted in  FIG. 9 .  FIG. 9  shows the screen  800  provided around the mandrel  502 , with support members  802  positioned between the screen  800  and the mandrel  502  to support the screen  800  on the mandrel  502 . 
       FIG. 10  shows another embodiment of a flow control valve that uses a screen. The  FIG. 10  flow control valve  900  has a screen  902  at its inlet to allow fluid to flow from outside the flow control valve  900  through the screen  902  into a space  904 . The fluid then flows from the space  904  along inlet path  906  into an inner chamber  908  of a housing  910  of the flow control valve  900 . Inside the chamber  908  is an electric motor  912  that is able to move an actuating rod  914 . A sealing member  916  is attached to the actuating rod  914  to allow the electric motor  912  to move the sealing member  916  longitudinally (in a longitudinal direction of the flow control valve  900 ). The fluid flows in the chamber  908  around the electric motor  912  and around an inner shroud  918  also provided in the chamber  908 . The inner shroud  918  has radial ports  920  to allow fluid to flow from outside the inner shroud  920  into an inner space  922  of the shroud  918 . The fluid that flows into the inner space  922  of the shroud  918  can then follow outlet path  924  to an outlet port  926  into the inner bore  600  of the mandrel  502 . 
       FIG. 10  shows the flow control valve  900  in its open position, in which the sealing member  916  is in a position that allows all flow ports  920  of the shroud  918  to be exposed to allow a full opening into the inner space  922  of the shroud  918 . The sealing member  916  is movable toward an end wall  928  of the housing  910  to provide a fully closed position. The sealing member  916  is also positionable to selectively close off ports  920  to provide intermediate choked positions. 
     The flow control valve  900  of  FIG. 10  also has pressure sensors P 1  and P 2 , with sensor P 1  measuring pressure within the chamber  908 , and sensor P 2  measuring pressure in the outlet path  922 . 
       FIGS. 11A-11C  illustrate another variation of a flow control valve  1000 . The flow control valve  1000  is a hydraulic flow control valve instead of an electric flow control valve as discussed above in connection with  FIGS. 5-10 .  FIG. 11C  shows the flow control valve  1000  in its full open position,  FIG. 11B  shows the flow control valve in its full closed position, and  FIG. 11A  shows the flow control valve in an intermediate position (choked position). 
     The mandrel  502  defines a structure  604  that has an inlet port  606  to allow fluid to flow from outside the flow control valve  1000  into an inner chamber  1002  defined inside a housing  1004  of the flow control valve  1000 . Within the chamber  1002  of the housing  1004  is an inflatable bladder  1006 . The inflatable bladder  1006  has an inner space  1008 . The bladder  1006  is arranged on a support member  1010 , where a portion of the support member  1010  has an inner fluid control line  1012  to allow communication of hydraulic pressure to the inner space  1008  of the inflatable bladder  1006 . 
     The inner control line  1012  is connected to a control module  1014 , which is controlled by an electrical line  1016 . The control module  1014  controls the application of hydraulic pressure to the control line  1012 , where a source of the hydraulic pressure is provided over a hydraulic control line  1018 . The control module  1014  can be controlled to apply hydraulic pressure from the hydraulic control line  1018  to the inner control line  1012  to cause hydraulic pressure to be communicated to the inner space  1008 , which causes the inflatable bladder  1006  to inflate.  FIG. 11A  shows the bladder  1006  inflated to an intermediate position. 
     In the intermediate position of  FIG. 11A , fluid flowing through the inlet port  606  is able to flow around the outside of the inflatable bladder  1006  to an outlet path  1020  to exit outlet port  1022 . 
       FIG. 11C  shows the inflatable bladder  1006  in its fully retracted position to maximize fluid flow past the inflatable bladder  1006 . On the other hand,  FIG. 11B  shows the bladder  1006  fully inflated such that the inflatable bladder  1006  engages the inner wall of the housing  1004 . This blocks flow coming through the inlet port  606  from reaching the outlet path  1020 . 
     As depicted in  FIG. 11A , pressure sensors  1024  and  1026  can be provided to monitor pressure on the two sides of the inflatable bladder  1006 . A pressure difference between the pressure sensors  1024  and  1026  (which can provide pressure data P 1  and P 2 , respectively) would indicate that the inflatable bladder  1006  is fully inflated to the closed position. 
     The flow control valve  1000  also has pressure sensors P 1  and P 2 , which are used to measure pressure on two sides of the chamber  1002  inside the flow control valve housing  1004 . 
     The flow control valve  1000  can also be provided in the side pocket of the mandrel  502  much like the electric flow control valve  500  depicted in  FIG. 6 . In a different embodiment, instead of providing a flow control valve in a side pocket, the flow control valve can be made to extend around the full circumference of the mandrel. This is depicted in  FIGS. 12A-12C  and  FIG. 13 .  FIGS. 12A-12C  depict a hydraulic flow control valve  1100  that has an inflatable bladder  1102  positioned inside an annular chamber  1104  of a housing  1106  of the flow control valve  1100 . The bladder  1102  extends around the outer circumference of an inner mandrel  1120 . The bladder  1102  has an inner space  1108  that is in communication with a control line  1110 . The control line  1110  is connected to the control module  1014  that is controllable by the electric line  1016 . The control module  1014  is able to apply hydraulic pressure from hydraulic control line  1018  to the inner space  1108  of the bladder  1102 . 
       FIG. 12A  shows the flow control valve  1100  in its choked position,  FIG. 12B  shows the flow control valve  1100  in its closed position, and  FIG. 12C  shows the flow control valve  1100  in its fully open position. Fluid flows through an inlet port  1112  to the inner chamber  1104  of the housing  1106 . In the choked position and open position of  FIGS. 12A and 12C , respectively, fluid can flow around the outside of the inflatable bladder  1102  to the outlet port  1114  that is provided on the inner mandrel  1120 . In the closed position, as depicted in  FIG. 12B , fluid flow is blocked between the inlet port  1112  and the outlet port  1114 . 
       FIG. 14  shows a multilateral well  1200  that has a main wellbore  1202  and multiple lateral branches  1204 ,  1206 ,  1208 , and  1210 . Also, a lower section  1212  is provided at the end of the main wellbore  1202 . 
     Within each of the lateral branches  1204 ,  1206 ,  1208 , and  1210 , and within the end section  1212  are provided completion assemblies that are similar to the assemblies discussed above in connection with  FIGS. 1-4 . Completion assembly  1214  is provided in lateral branch  1204 , completion assembly  1216  is provided in lateral branch  1206 , completion assembly  1218  is provided in lateral branch  1208 , completion assembly  1220  is provided in lateral branch  1210 , and completion assembly  1222  is provided in the lower wellbore section  1212 . Also depicted in  FIG. 14  is a main completion assembly  1201  that extends through portions of the main wellbore  1202  adjacent corresponding lateral completion assemblies  1214 ,  1216 ,  1218 , and  1220 , and connects to the completion assembly  1222  in the lower completion section  1212 . This is contrasted to conventional completion systems that include separate main completion segments stacked in the main wellbore  1202 , where each main completion segment is separately coupled to a respective lateral completion assembly. In such a conventional system, the main completion segments are run in separately and sequentially after each corresponding lateral completion assembly is deployed, with the separately run main completion segments stacked as they are run into the main wellbore. In contrast, the main completion assembly  1201  of  FIG. 14  is deployed as a continuous string through the main wellbore  1202  and past the lateral completion assemblies to the lower completion assembly  1222 . The main completion assembly  1201  is able to communicate fluids with the lateral branch bores, and communicate electrically with the lateral completion assemblies. 
     The following figures describe various stages of completing one of the lateral branches of the multilateral well  1200 . As depicted in  FIG. 15 , focus is made on lateral branch  1210 , for example. 
     The main wellbore section  1202  of the multilateral well  1200  is lined with casing  1223 . A first index casing coupling  1224  is provided in a lower position of the casing  1223 , where the index casing coupling  1224  is located in the main wellbore  1202  before the lateral branch  1210 . A second index casing coupling  1226  is provided past the lateral branch  1210 . The index casing couplings  1224  and  1226  are aligned azimuthally so that subsequent completion equipment can be properly oriented with respect to the lateral branch  1210 . The second (lower) index casing coupling  1226  is used to azimuthally position a deflector (described below) to orient a tool (e.g., drilling tool) toward the lateral branch. The second (upper) index casing coupling  1224  is aligned with the lower index casing coupling  1226  to orient deployment of various equipment, as discussed further below. The casing  1223  has a pre-milled window  1228  to allow for communication between the inside of the casing  1223  and the lateral branch  1204 . 
     After running the casing or liner  1200  in the main bore, drilling of the multilateral branch through pre-milled windows  1228  as shown in  FIG. 15  is performed. All the multilateral branches are drilled before running completion. 
       FIG. 16  shows deployment of the completion system  1222  in the lower section  1212  of the main wellbore  1202 . The completion assembly  1222  has packers  1302 ,  1304 , and  1306  to define multiple zones. Also, the completion assembly  1300  has adjustable flow control valves  1308  and  1310  in the two respective zones. Screens  1312  and  1314  are provided in the two zones for sand control. The adjustable flow control valves  1308  and  1310  can be any of the flow control valves in  FIGS. 5A-13 . 
     An electric cable  1316  is provided to control the adjustable flow control valves  1308  and  1310 . The electrical cable  1316  is electrically connected to a first (e.g., female) inductive coupler portion  1318 . The female inductive coupler portion  1318  is used to mate with another (e.g., male) inductive coupler portion (discussed below) to allow for electrical energy to be provided to the electrical cable  1316  for the purpose of controlling the adjustable flow control valves  1308  and  1310 . 
       FIG. 16  shows deployment of a completion assembly in the main wellbore, in this case the lower section  1212  of the main wellbore. Next, the lateral branch  1210  is completed by deploying the completion assembly  1220  ( FIG. 14 ) in the lateral branch  1210 . To perform such deployment, as depicted in  FIG. 17 , a two-part deflector  1230  is run to a location of the second indexing casing coupling  1226  so that the deflector  1230  engages the indexing casing coupling  1226 . The two-part deflector  1230  has a retrievable part  1230 A, and a non-retrieved part  1230 B that stays in the wellbore after retrieval of the retrievable part  1230 A from the wellbore. The deflector  1230  has a mating indexing member  1232  for engaging the indexing casing coupling  1226  to properly position and orient (azimuthally) the deflector  1230  in the wellbore. The proper azimuthal orientation of the deflector  1230  means that the inclined surface  1234  of the deflector  1230  is aligned with the lateral branch  1210 . As a result, any subsequent equipment lowered into the casing  1223  will be directed into the lateral branch  1210 . 
     The provision of completion equipment into the lateral branch  1210  is depicted in  FIG. 18 , which shows completion assembly  1220  provided into the lateral branch  1210 . The completion assembly  1220  has packers  1320 ,  1324 , and  1326  to define two zones. The packer  1320  can be made of a swellable material (such as swellable rubber) to swell at the junction to provide the desired seal. Alternatively, the isolation packer  1320  can be a compression-based isolation packer. 
     A first zone  1328  defined by packers  1320  and  1324  includes a swivel  1330 . A second zone  1332  defined by isolation packers  1324  and  1326  includes an adjustable flow control valve  1334  and a screen  1336 . The flow control valve  1334  is electrically connected to a electrical line  1338  that passes through the swivel  1330  and through the isolation packers  1324  and  1320  to a third inductive coupler portion  1340  (which can be a female inductive coupler portion). The inductive coupler portion  1340  is attached to a connector housing  1342  that is engaged to the first indexing casing coupling  1224  for proper positioning and orientation of the pre-milled window  1345  in the connector housing or liner  1342  with the bore of the main bore completion. The connector housing  1342  has a pre-milled window  1345 —to allow for retrieving the retrievable deflector  1230 A after running the completion in the lateral branch. Properly oriented window  1345  in the housing  1342  allows passing the main bore completion through the window  1345 . The connector housing  1342  extends from the main wellbore to the lateral branch  1210 . 
     In some embodiments, the connector housing  1342  (also referred to as a junction liner) is run together with lateral completion equipment. As depicted, the junction liner  1342  is engageable with the upper index casing coupling  1224 . Since the upper index casing coupling  1224  is azimuthally aligned with the lower index casing coupling  1226 , engagement of the junction liner  1342  with the upper index casing coupling  1224  allows for the window  1345  of the junction liner  1342  to line up with the lower part of the main wellbore. 
     The lower end of the connector housing  1342  is attached to the swivel  1330 . The swivel is in turn connected to a pipe section  1346  that extends into the lateral branch  1210 . The swivel  1330  allows the junction liner  1342  to freely rotate in relation to the lateral branch completion  1346  to allow for proper alignment of window  1345  in the junction liner installed in the lateral branch and the main wellbore equipment. The swivel is not allowed to rotate while running in the hole. It is unlocked and allowed to rotate once the completion is close to the indexing coupling  1224 . 
     The upper end of the connector housing  1342  is attached to a liner packer  1348 , which when set seals against the casing  1223 . A work string  1350  is provided through the connector housing  1342  for running of the lateral completion. 
       FIG. 19A  is a cross-sectional view of a section of the completion system depicted in  FIG. 18 . As depicted in  FIG. 19A , a longitudinal groove  1352  is provided in the connector housing  1342  to run the electrical cable  1338 , according to some embodiments. The connector housing  1342  has a pre-milled window  1345 . Moreover, the casing  1223  has a pre-milled window  1228 . 
     As depicted in  FIG. 19B , instead of providing the groove  1352  ( FIG. 19A ) in the connector housing  1342 , rails  1353  can be provided instead, where the rails  1353  run along the length of the connector housing  1342 . In one embodiment, the rails  1353  can be welded to the outer surface of the connector housing  1342 . Other attachment mechanisms can also be used in other implementations. Also, a cover  1355  can be used to cover the cable  1338  that runs between the rails  1353 . 
       FIG. 19C  shows yet another embodiment in which a groove  1352 A formed in a connector housing  1342 A is enlarged to allow for the provision of both the electrical cable  1338  as well as a hydraulic control line  1339 , which can be used to control hydraulic components in various completion assemblies. 
     Once the completion assembly  1220  has been set in the lateral branch  1210 , the work string  1350  is pulled out of the wellbore to result in the configuration depicted in  FIG. 20 . Next, the retrievable part  1230 A of the deflector  1230  is retrieved from the wellbore, as depicted in  FIG. 21 . After retrieval of the retrieved part  1230 A, the non-retrieved (or permanent) part  1230 B remains in the wellbore. After the deflector has been retrieved, the main completion assembly ( 1201  in  FIG. 14 ) is run into the main wellbore, as depicted in  FIG. 22 . The main completion assembly  1201  includes completion tubing  1400  and a completion packer  1402  that is set between the tubing  1400  and the casing  1223 . The completion tubing  1400  has a first male inductive coupler portion  1404  and a second male inductive coupler portion  1406  for positioning adjacent female inductive coupler portions  1340  and  1318 , respectively. An electrical cable  1408  that is run along the completion tubing  1400  extends through the completion packer  1402  and a length compensation joint  1410  to the first male inductive coupler portion  1404 . The electrical cable  1408  further extends from the first male inductive coupler portion  1404  through another length compensation joint  1412  to the second male inductive coupler portion  1406 . The first set of inductive coupler portions  1404  and  1340  provide a first inductive coupler, and the second set of inductive coupler portions  1406  and  1318  provide a second inductive coupler. The first inductive coupler provides communication of electrical signaling to the completion assembly  1220  in the lateral branch  1210 . The second inductive coupler provides electrical communication to the completion assembly  1222  in the lower main wellbore section  1212 . 
     To properly align the inductive coupler portions  1404 ,  1406  with respective inductive coupler portions  1340  and  1318 , a selective locator  1414  is provided. The selective locator  1414  can be provided on the connector housing  1342 . A mating selective locator  1416  is provided on the outside of the completion tubing  1400  such that when the selective locators  1414  and  1416  mate, that is an indication that the inductive coupler portions are properly aligned. 
     The discussion of  FIGS. 14-22  assume a casing that has been pre-milled with a window to allow communication with the lateral branch. In contrast, as depicted in  FIG. 23 , a casing  1500  without a pre-milled window is installed in a main wellbore  1502 . The casing  1500  has first and second index casing couplings  1504  and  1506  intended to be provided on either side of the lateral branch when it is milled. 
     As depicted in  FIG. 24 , the completion assembly  1222  is installed in the lower section  1212  of the main wellbore  1502 . Next, as shown in  FIG. 25 , a two-part defector  1508  (having a retrievable part  1508 A and a permanent part  1508 B) is run into the wellbore and engaged with the indexing casing coupling  1506  to position and orient the deflector  1508 . Following deployment of the deflector  1508 , a lateral window  1510  is milled in the casing  1500 , and a lateral branch  1512  is drilled through the milled lateral window  1510 . The remaining tasks are similar to the tasks of  FIGS. 18-22  discussed above. 
     An alternative communications arrangement is depicted in  FIG. 26  to allow for communication with lateral branches  1602 ,  1604 , and a lower section  1606  of a main wellbore  1600 . It is assumed that a completion tubing  1608  has been positioned in the main wellbore  1600 . A packer  1610  on the main tubing  1600  is set against the wellbore. 
     The main tubing  1600  also includes a control station  1612 . The control station  1612  is electrically connected over an electrical cable  1614  to the earth surface. The control station  1612  can include a processor and possibly a power and telemetry module to supply power and to communicate signaling. The control station  1612  can also optionally include sensors, such as temperature and/or pressure sensors. 
     The control station  1612  is electrically connected over a first electrical cable segment  1616  to a first inductive coupler portion  1618 . The control station  1612  is also connected over a second electrical cable segment  1620  to another inductive coupler portion  1622 . Moreover, the control station  1612  is electrically connected over a third electrical cable segment  1624  to a third inductive coupler portion  1626 . 
     A benefit of using the arrangement of  FIG. 26  is that the control station  1612  is directly connected over respective cable segments to corresponding inductive coupler portions, which avoids the issue of power loss due to serial connection of multiple inductive coupler portions. 
       FIG. 27  shows a further communications arrangement, which is modified from the arrangement of  FIG. 26  in that a common electrical cable segment  1630  is used to electrically connect the control station  1612  to the inductive coupler portions  1618 ,  1622 , and  1626 . In the  FIG. 27  implementation, one electrical cable segment is used, rather than three separate electrical cable segments. 
       FIG. 28  shows a completion system that includes an electro-hydraulic wet connect that allows for wet connection of both electrical signaling, as well as hydraulic control conduits. As depicted, a main wellbore  1700  is lined with casing  1702  that extends partway into the main wellbore  1700 . An open hole section  1704  is provided below the casing  1702 . The open hole section has the completion assembly deployed that includes isolation packers  1705 ,  1706  and  1708  to define zones  1710  and  1712 . The zone  1710  includes a screen  1714  and an adjustable flow control device  1716 , and the zone  1712  includes a screen  1718  and an adjustable flow control device  1720 . The flow control devices  1716  and  1720  are used to communicate fluids into the inner bore  1722  of the completion assembly. It is assumed that the flow control devices  1716  and  1720  are actuated using both electrical and hydraulic control signals. As a result, the flow control devices  1716  and  1720  are connected to an electrical cable segment  1724  and a hydraulic control line segment  1726 . The electrical cable segment  1724  is electrically connected to an inductive coupler portion  1728 , and the hydraulic control line portion  1726  is hydraulically connected to a hydraulic connection mechanism  1730 . The hydraulic connection mechanism includes a groove  1732  that can run around the circumference of a connection sub  1734 . Seals  1736  and  1737  are provided on the two sides of the groove  1732  to provide a seal against leakage of hydraulic fluids. The groove  1732  allows for hydraulic connection between the hydraulic control line segment  1726  and another hydraulic control line segment  1738 , which extends from the hydraulic connection mechanism  1730  to a length compensation joint  1740 . The hydraulic control line segment  1738  continues around the length compensation joint  1740  and extends upwardly through a packer  1742 . 
     The hydraulic connection mechanism  1730  is a hydraulic wet connect mechanism that allows for a hydraulic connection to be made in wellbore fluids between an upper completion section and a lower completion section. 
     The inductive coupler portion  1728  communicates with another inductive coupler portion  1744 , which is electrically connected to an electrical cable segment  1746  that extends upwardly through the length compensation joint  1740  and through the packer  1742 . The inductive coupler portions  1728  and  1744  enable an electrical wet connect to be made between an upper completion section and a lower completion section. 
       FIG. 29  shows a multilateral completion system that also provides for electro-hydraulic wet connect. As depicted in  FIG. 29 , a hydraulic wet connect mechanism  1802  similar to the hydraulic wet connect mechanism  1730  of  FIG. 28  is provided to allow for hydraulic connection between hydraulic control line segment  1804  and hydraulic control line segment  1806 . 
     Inductive coupler portions  1808  and  1810  form an inductive coupler to electrically couple an electrical cable segment  1812  to an electrical cable segment  1814 . The remaining components of  FIG. 29  are similar to the multilateral system depicted earlier. 
     While the invention has been disclosed with respect to a limited number of embodiments, those skilled in the art, having the benefit of this disclosure, will appreciate numerous modifications and variations therefrom. It is intended that the appended claims cover such modifications and variations as fall within the true spirit and scope of the invention.