CROSS-REFERENCE TO RELATED APPLICATIONS 
     This application claims priority to U.S. Provisional Patent Application having Ser. No. 60/978,983, filed on Oct. 10, 2007, which is incorporated herein by reference. 
    
    
     BACKGROUND 
     Hydrocarbon producing formations typically have sand commingled with the hydrocarbons to be produced. For various reasons, it is not desirable to produce the commingled sand to the earth&#39;s surface. Thus, sand control completion techniques are used to prevent the production of sand. 
     Gravel packing is one method for controlling sand production. Although there are variations, gravel packing usually involves placing a sand screen around the section of the production string containing the production inlets. This section of the production string is aligned with perforations. Gravel slurry, which is typically gravel particulates carried in a viscous transport fluid, is pumped through the tubing into the formation and the annulus between the sand screen and the casing or between the sand screen and the open hole. The deposited gravel holds the sand in place preventing the sand from flowing to the production tubing while allowing the production fluids to be produced therethrough. 
     In multi-zone wells or in a well having multiple flow sections, flow control devices have been used to control fluid flow through orifices formed between the tubing bore and an annulus between the tubing and casing. However, if sand face completion equipment including gravel packing is installed, then the annulus is typically filled, which makes it difficult to position such flow control devices in the proximity of sand control equipment. Accordingly, the formation fluid must first flow generally radially through the sand control device before flowing to the flow control device. One option is to install the flow control device inside a tubing bore in the proximity of the production zone. However, this reduces the available flow area for production flow. 
     Three-way sub systems with sliding sleeves inside an internal isolation string have also been used for zonal isolation. A screen wrapped sliding sleeve is also a common system. For example, U.S. Pat. No. 3,741,300 discloses a sliding sleeve within a screen assembly. However, the &#39;300 patent describes a 3-way sub system and it is specifically intended for stand alone screen applications (no pumping). 
     U.S. Pat. No. 5,337,808 discloses an apparatus where the screen wrapping is placed directly over and around the flow control device. U.S. Pat. No. 6,220,357 discloses a similar apparatus. 
     U.S. Pat. No. 5,609,204 and U.S. Pat. No. 5,579,844 disclose an apparatus having sliding sleeves inside sand control screens in combination with components for supporting gravel packing operations such as polished bore receptacles and port closure sleeves. 
     U.S. Pat. No. 5,865,251 discloses an isolation valve “adjacent” or “interior” of the screen assembly which covers the apertures of the valve. 
     U.S. Pat. No. 6,405,800 discloses an isolation valve that is positioned in the screen base pipe underneath the screen jacket. 
     U.S. Pat. No. 6,343,651 and U.S. Pat. No. 6,446,729 disclose a flow control valve that is coupled to a screen assembly. It is not surrounded by and is offset from the screen wrapping. The valve is in fact not integral to the screen assembly but an added component which is hydraulically coupled to the screen and base pipe annulus to control flow into the main bore. 
     U.S. Pat. No. 6,464,006 discloses an apparatus having flow screens with flow closure members. The figures presented in U.S. Pat. No. 6,464,006 illustrate a three-way sub system, but both ends of the isolation pipe are shown affixed to the screen assembly. 
     U.S. Pat. No. 6,719,051 and U.S. Pat. No. 7,096,945 disclose a screen assembly with openings in the base pipe and a valve associated with the openings in the base pipe to control flow through the openings. 
     U.S. Publication No. 2007/0084605 discloses a screen assembly with at least one production screen valve. 
     There is still a need for improved flow control devices that provide incremental choking of the flow and that may be used in sand control completion equipment. There is also a need for a coupling tool that supports a flowpath between two screens without the use of an isolation string. 
     SUMMARY 
     An apparatus including a pipe coupling and integrated valve and method of using the same is disclosed. The apparatus can include a first outer tubular member and a first inner tubular member. The first outer tubular member and the first inner tubular member can define a first space therebetween. The first inner tubular member can have a first internal bore. The system can also include a second outer tubular member and a second inner tubular member. The second outer tubular member and the second inner tubular member can define a second space therebetween. The second inner tubular member can have a second internal bore formed therethrough. A first coupling flowpath can be positioned between the first and second spaces. A second coupling flowpath can be positioned between the first and second internal bores. A selectively closeable flowpath can be positioned between the first coupling flowpath and the second coupling flowpath. 
     One or more embodiments of the method of using the multi-zone gravel pack system with pipe coupling an integrated valve can include conveying a completion string downhole. An annulus can be formed between the completion string and a wellbore. The completion string can include at least two sand completion systems, a communication port positioned adjacent to each sand completion system, and a position indicator positioned adjacent to each communication port. Each sand completion system can include one or more apparatuses. The method can further include, positioning one of the sand completion systems adjacent to a lower hydrocarbon bearing zone, and the other sand completion system adjacent to an upper hydrocarbon bearing zone. Communication between the annulus adjacent the upper hydrocarbon bearing zone and the internal bores of the adjacent sand completion system can be prevented, and communication between the annulus adjacent the lower hydrocarbon bearing zone and the internal bores of the adjacent sand completion system can be allowed. Gravel can be provided to a portion of the annulus adjacent to the lower hydrocarbon bearing zone. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       So that the recited features can be understood in detail, a more particular description, briefly summarized above, may be had by reference to one or more embodiments, some of which are illustrated in the appended drawings. It is to be noted, however, that the appended drawings illustrate only typical embodiments and are therefore not to be considered limiting of its scope, for the invention may admit to other equally effective embodiments. 
         FIG. 1  depicts an illustrative sand completion system in a closed position, according to one or more embodiments described. 
         FIG. 2  depicts the illustrative sand completion system of  FIG. 1  in an open position, according to one or more embodiments described. 
         FIG. 3  depicts an illustrative coupling tool, according to one or more embodiments described. 
         FIG. 4  depicts an illustrative view of one or more sand completion systems integrated into a completion string, according to one or more embodiments described. 
         FIG. 5  depicts an illustrative service string for performing multi-zone gravel pack operations, according to one or more embodiments described. 
         FIGS. 6-12  are schematics of the completion string of  FIG. 3 , and depict a sequential illustration thereof configured to perform a gravel pack operation on a wellbore, according to one or more embodiments described. 
     
    
    
     DETAILED DESCRIPTION 
     A detailed description of the one or more embodiments, briefly summarized above, is provided below. As used herein, the terms “up” and “down”; “upper” and “lower”; “upwardly” and “downwardly”; “upstream” and “downstream”; and other like terms are merely used for convenience to describe spatial orientations or spatial relationships relative to one another in a vertical wellbore. However, when applied to equipment and methods for use in deviated or horizontal wellbores, it is understood to those of ordinary skill in the art that such terms are intended to refer to a left to right, right to left, or other spatial relationship as appropriate. 
       FIG. 1  depicts an illustrative sand completion system  100  in a closed position, according to one or more embodiments. The sand completion system  100  can include two or more screen assemblies  110 ,  112  having a coupling tool  119  disposed therebetween. Each screen assembly  110 ,  112  can include an outer tubular member  106 ,  108  disposed about a body or mandrel (“inner tubular member”)  102 ,  104 . For example the first assembly  110  can be the first outer tubular member  106  about the first inner tubular member  102 , and the second assembly  112  can include the second outer tubular member  108  about the second inner tubular member  104 . 
     The outer tubular members  106 ,  108  can include a screen or particulate restricting member. The screen or particulate restricting member can be wire wrapped screens or any other known screen. For example, one or more portions of the outer tubular member can be constituted by wire wrap screen. 
     Each inner tubular member  102 ,  104  can be base pipe, production tubing, or any other common downhole tubular member. In one or more embodiments, the body  102  (“first inner tubular member  102 ”) can have an inner flowpath or internal bore  126  formed therethrough, and the second body  104  (“second inner tubular member  104 ”) can have an inner flowpath or internal bore  128  formed therethrough. 
     A space or gap  114 ,  116  is formed between an outer diameter of each inner tubular member  102 ,  104  and the surrounding screen  106 ,  108 . Each space or gap  114 ,  116  defines an outer flowpath about its respective inner tubular member  102 ,  104 . For example, a first flowpath or first space  114  is formed between the first inner tubular member  102  and the first screen  106 . The second flowpath or second space  116  is formed between the second inner tubular member  104  and the second screen  108 . 
     The coupling tool  119  can include a first coupling flowpath  118 , a second coupling flowpath  120 , and a third coupling flowpath  122  formed therethrough. The first coupling flowpath  118  can be in fluid communication, and thus “couple” the first flowpath or space  114  to the second flowpath or space  116 . The second coupling flowpath  120  can be in fluid communication, and thus “couple” the first inner flowpath  126  to the second inner flowpath  128 . The third coupling flowpath  122  can be in fluid communication, and thus “couple” the first coupling flowpath  118  and the second coupling flowpath  120 . 
     The coupling tool  119  can further include a flow control device  124 . The flow control device  124  allows the outer flowpaths  114 ,  116  to be selectively communicated with the inner flowpaths  126 ,  128 . In one or more embodiment, the flow control device  124  can be integrated into the coupling tool  119 . In one or more embodiments, the flow control device  124  can be a stand alone component that can be attached to the coupling tool  119 . 
     In one or more embodiments, the flow control device  124  can be a sliding sleeve. An illustrative sliding sleeve can simply be a tubular member disposed within the annulus of the coupling tool  119 . In one or more embodiments, the flow control device  124  can be a sliding sleeve having one or more apertures or holes formed therethrough. In one or more embodiments, the flow control device  124  can be a remotely operated valve, or any other downhole flow control device. An illustrative flow control device  124  is described in U.S. Pat. No. 6,446,729. 
     The use of the flow control device  124  with the coupling tool  119  can allow for flexibility in the design of the flow control device  124  without affecting the manufacturing and design of the sand screen assemblies  110 ,  112 . Furthermore, by allowing the complexity of the flow control device  124  to be varied independent of the design of the sand screen assemblies  110 ,  112 , various levels of modularity for the sand completion system  100  can be obtained. 
     When the flow control device  124  is in a closed position, the first coupling flowpath  118  is not in communication with the second coupling flowpath  120 ; however, the first flowpath or space  114  is in communication with the second flowpath or space  116 , and the first inner flowpath  126  is in communication with the second inner flowpath  128 . Furthermore, the flowpaths  114 ,  116 ,  118  can be in communication with the exterior of the screen assemblies  110 ,  112 . However, the flowpaths  126 ,  128 ,  120  are prevented from communicating with the exterior of the sand screen assemblies  110 ,  112 . 
     In the open position, the first coupling flowpath  118  is in communication with the second coupling flowpath  120 , and the third coupling flowpath  122 , as depicted in  FIG. 2 . When the flow control device  124  is in an open position, each of the flowpaths  114 ,  116 ,  126 ,  128 ,  118 ,  122 ,  120  is in communication with the exterior of the screen assemblies  110 ,  112 . Therefore, the inner flowpaths  126 ,  128  are in communication with the exterior of the sand screen assemblies  110 ,  112  when the second coupling flowpath  120  is in communication with the first coupling flowpath  118 . 
       FIG. 3  depicts an illustrative coupling tool  119 , according to one or more embodiments. The coupling tool  119  can include one or more housings  310 , one or more shrouds  360 , one or more flow control device  124 , one or more first coupling flowpaths  118 , one or more second coupling flowpaths  120 , one or more pipe couplings  320 , one or more torque transfer shrouds (two are shown  330 ,  332 ), one or more load inserts  340 , one or more end rings (two are shown  350 ,  352 ), one or more pipe joints (two are shown  370 ,  372 ), and one or more third coupling flowpaths  122 . 
     The length of the coupling tool  119  can be determined by the size of the flow control device  124 . The shroud  360  can be placed at least partially about the housing  310 , and pipe joints  370 ,  372 . The first coupling flowpath  118  can be formed between the shroud  360  and the housing  310  and pipe joints  370 ,  372 . In one or more embodiments, the shroud  360  can be a solid tubular shroud. The end rings  350 ,  352  can be positioned adjacent to the shroud  360 . Since the length of the coupling tool  119  can be determined by the length of the flow control device  124 , a solid shroud would create a section of a sand completion system  100 , without screens that may be longer than encountered in typical applications. This could have an adverse effect on the placement of the sand control treatment. Such effects can be poor packing around the coupling area and premature bridging at the top of the coupling area. In this situation, the shroud can include slotted openings (not shown). For example, a slotted liner can be used. The slotted liner can allow for leak off during gravel placement. Therefore, in one or more embodiments, the entire shroud or a portion of the shroud can include the slotted openings. 
     The flow control device  124  can be disposed within the housing  310 . The housing  310  can be positioned between the pipe joints  370 ,  372 . The housing can have a plurality of apertures  311  or holes formed therethrough. The apertures  311  can allow communication between the second coupling flowpath  120  and the third coupling flowpath  122 . The apertures or holes can be selectively opened and closed by the flow control device  124 . For example, if the flow control device  124  is a sliding sleeve the sliding sleeve can be configured to selectively prevent flow through the apertures  311 , thus preventing communication between the third coupling flowpath  122  and the second coupling flowpath  120 . 
     The pipe joints can be tubular members configured to attach or otherwise engage inner tubular members of a double wall tubular assembly, such as screen assemblies  110 ,  112 . A pipe coupling  320  can be positioned adjacent to at least one of the pipe joints  370 ,  372 , such as “upper” pipe joint  370 , as depicted in  FIG. 3 . 
     The torque shrouds  330 ,  332  can be positioned about a portion of the pipe joint  370 ,  372 , and the pipe coupling  320 . The torque shrouds can be production tubing or other known downhole tubing. The torque shrouds  330 ,  332  can allow for the transfer of torque. The “upper” torque shroud  330  can be floating allowing the “upper” torque shroud  330  to move. The “lower” torque shroud  332  can be fixed to the pipe joint  372 . 
     A load insert  340  can be positioned adjacent to the “upper” torque shroud  330 . The load insert  340  can interface with a screen table/plate known in the industry and temporarily support the hanging weight of the completion during make up operations at surface. 
       FIG. 4  depicts an illustrative view of one or more sand completion systems  100  integrated into a completion string  400 , according to one or more embodiments. The completion string  400  can include two or more sand completion systems  100  (two are shown), two or more isolation packers (two are shown  406 ,  408 ), one or more internal upsets  420 , two or more port closure sleeves (two are shown  430 ,  432 ), and two or more position indicators (two are shown  440 ,  442 ). The completion string  400  can include any type of well treatment strings, including well treatment strings that are used during subterranean formation fracturing, completion, or other operations. A suitable completion string  400  can be used for gravel packing operations, chemical treatment operations, and/or other common workover operations. 
     The isolation packers can be used to isolate hydrocarbon bearing zones (not shown) located within a producing formation (not shown). For example, the first isolation packer can be disposed adjacent to an upper hydrocarbon bearing zone, the second isolation packer can be disposed adjacent to a lower hydrocarbon bearing zone, and a third isolation packer (not shown) can be disposed below the lower hydrocarbon bearing zone. In one or more embodiments, the third packer can be installed in a wellbore (not shown) prior to the installation of the completion  400  and the completion  400  can be configured to attach to or otherwise engage the third isolation packer, or in the alternative the isolation packer can be integrated with the completion  400 . The isolation packers  406 ,  408  can be compression or cup packers, inflatable packers, “control line bypass” packers, polished bore retrievable packers, any other common downhole sealing mechanism, or combinations thereof. The isolation packers  406 ,  408  can be set in the wellbore by the use of mechanical means or by any other known method. 
     The internal upset  420  can be disposed adjacent to the second packer  408 . The internal upset  420  can allow for a more direct reverse flow. The internal upset  420  can be an internal upset commonly known in the art. 
     The first port closure sleeve  430  can be disposed adjacent to the first packer  406 . The second port closure sleeve  432  can be disposed adjacent to the internal upset  420 . The port closure sleeves can be engaged by a service tool (not shown), and can allow the service tool to communicate with the exterior of the completion  400 . The port closure sleeves  430 ,  432  can be any port closure sleeve commonly known in the art. An illustrative communication port closure sleeve is described in more detail in U.S. Pat. No. 7,066,264. The port closure sleeves  430 ,  432  can have polished bore receptacles (not shown). 
     The position indicators  440 ,  442  can be disposed adjacent to the port closure sleeves  430 ,  432 . The position indicators  440 ,  442  can be used to position a service tool for engagement with the port closure sleeves  430 ,  432 . Each position indicators  440 ,  442  can be a “Go/no go” collar, for example. A suitable indicator is described in U.S. Pat. No. 7,066,264. Of course, the position indicators  440 ,  442  can be any other type of position indicator known in the art. 
     Additional coupling tools  119  can be positioned at each end of each sand completion system  100 . In one or more embodiments, one or more of the coupling tools  119  of one or more of the sand completion systems  100  can be modified by removing the third coupling flowpath  122 , and the flow control device  124 . Such modified coupling tool (not shown) could provide the first coupling flowpath  118  and the second coupling flowpath  120 . However, the first coupling flowpath  118  would not be in communication with the second coupling flowpath  120 . In one or more embodiments, such modified coupling tool could be used as a contingency perforating target. For example, a perforating gun can be run into the wellbore, located adjacent the modified coupling tool and perforate holes into the modified coupling tool to allow for communication between the completion bore and the annulus. 
       FIG. 5  depicts a service string  500  for performing multi-zone gravel pack operations, according to one or more embodiments. The service string  500  can include one or more tubular members  510 , one or more gravel pack setting modules  520 , one or more spacer strings  530 , one or more cross over port bodies  540 , one or more reversing valves  560 , one or more shifting tools  580 , and one or more sliding sleeve collets  590 . 
     The tubular member  510  can be production tubing or other tubing commonly used downhole. The tubular member  510  can have a length sufficient to run from the surface down to the top of the completion  400 . 
     The gravel pack setting module  520  can be engaged or otherwise supported by the tubular member  510 . The gravel pack setting module  520  can be any gravel pack setting module known in the art. The gravel pack setting module  520  can be configured to engage or otherwise attach to the first packer  406 . The gravel pack setting module  520  can be used to set the top isolation packer, such as first packer  406 . 
     The spacer string  530  can be positioned adjacent to the packer setting module  520 . The spacer string  530  can be a blank pipe or other tubing member. The spacer string  530  can have a length long enough to extend the shifting tool  580  bellow the lowermost flow control device  124  to be operated. For example, the spacer string  530  can be long enough to extend the shifting tool  580  below the flow control device  124  of the lowermost coupling tool  119  of a “lower” sand completion system  100 . 
     The cross over port body  540  can be disposed on the spacer string  530  above the shifting tool  580 . The cross over port body  540  can be any cross over port body known in the art. In one or more embodiments, the cross over port body  540  can be equipped with a shear down ball seat  542 . The crossover port body  540  can sealably interface with the completion bore  405  at various locations to support multi-zone gravel pack operations. The sealable interface can be achieved using methods commonly known in the art. For example, the sealable interaction can either be by seals (not shown), such as bonded seals or cup seals, on the outer diameter of the cross over port body  540  and polished bore receptacles (not shown) integrated into the completion or the inverse using internal seals (not shown) integrated with the completion  400  and polished surfaces (not shown) on the outer diameter of the cross over port body  540 . 
     The reversing valve  560  can be positioned below the crossover port body  540 . The reversing valve  560  can restrict or prevent flow downhole past the service string  500 . In one or more embodiments, it would be desirable that the reversing valve  560  operate without impairing movements of the service tool  500 , due to hydraulic locking issues. One way to provide such functionality is to use a full bore set down module or equivalent technology with a modified valve that has a small hole through it to allow for minimal leak through while supporting greater reverse out pressures/rates. In one or more embodiments, the reversing valve  560  can have an anti-swab feature. The reversing valve  560  can be any valve known in the art. 
     The shifting tool  580  can be positioned below the reversing valve  560 . The shifting tool  580  can be adapted to at least actuate the flow control devices  124  of the sand completion assemblies  100 . In one or more embodiments, the shifting tool  580  can actuate the flow control devices  124  and the port closure sleeves  430 ,  432 . The shifting tool  580  can be a collet, a magnetic actuator, another common down hole shifting tool, or combinations thereof. 
     The sliding sleeve shifting tool  590  can be disposed below the shifting tool  580 . The sliding sleeve shifting tool  590  can be configured to actuate at least the port closure sleeves  430 ,  432 . In one or more embodiments, the sliding sleeve shifting tool  590  can be configured to open the flow control device  124  and the port closure sleeves  430 ,  432 . In one or more embodiments, the sliding sleeve shifting tool  590  can be a collet, a magnetic actuator, another common down hole shifting tool, or combinations thereof. The interaction of the service string  500  and the completion string  400  is described in more detail in  FIGS. 6-12 . 
       FIG. 6  depicts an embodiment of the completion string  400  configured to perform a gravel pack operation on a wellbore  600 , according to one or more embodiments. The service string  500  can be positioned within the completion bore  405  of the completion string  400 . When used with cased holes, perforating steps can be taken before the completion string  400  is run-in the wellbore  600 , and the sump packer  603  can be set. In one or more embodiments, the perforation steps, the setting of the sump packer  603 , and the placement of the completion string  400  into the wellbore can be performed in the same trip. 
     To run-in the completion string  400  the gravel pack setting module  520  can be secured or otherwise engaged with the first isolation packer  406 , and the “upper” sand completion system  100  can be placed adjacent to hydrocarbon bearing zone  605 , and the “lower” sand completion system  100  can be placed adjacent to the hydrocarbon bearing zone  610 . The spacing of the sand completion systems  100  can be determined by logging information or other downhole measurements. An annulus  620  can be formed between the completion string  400  and the wall  602  of the borehole  600 . Upon positioning of the sand completion systems  100 , the first packer  406  can be set and the packer module  520  can be released from the first packer  406 , as depicted in  FIG. 6 . As depicted in  FIG. 7 , the rest of the packers, such as second packer  408  can be set and possible tested. Of course, in one or more embodiments, each packer  406 ,  408  can be set before the packer module  520  is released from the first packer  406 . In one or more embodiments, one or more packers can be tested before the packer module  520  is released from the first packer  406 . 
     Turning now to  FIG. 8 , the service string  500  can be used to open at least the lower most flow control device  124  of the “lower” sand completion system  100 , and the second port closure sleeve  432 . The service string  500  can then be positioned to place gravel slurry  630  into the annulus  620  adjacent to the “lower” sand completion system  100 . When the gravel slurry  630  is placed in the annulus  620 , it is driven within the portion of the annulus  620  adjacent to the second hydrocarbon bearing zone  610 , and dehydrates. As the gravel slurry  630  dehydrates a fluid portion  632 , such as clean carrier fluid, can migrate through the first screen assembly  110  and the second screen assembly  112  of the “lower” sand completion system  100 , and gravel  364  from the gravel slurry  630  can be held within the annulus  620  by the sand screen assemblies  110 ,  112  of the “lower” sand completion system  100 . The fluid portion  632  can migrate flow thorough the flowpaths  114 ,  116 ,  118  of the “lower” sand completion system  100 , and can flow through the opened flow control devices  124  into the completion bore  405  adjacent to the “lower” hydrocarbon bearing zone  610 . Fluid can travel uphole as depicted by the arrows in  FIG. 8 . After the gravel  634  has formed a tight pack in the annulus  620 , the placing of gravel slurry  630  can be stopped. The excess gravel slurry  900  can then be reversed out to the surface, as depicted in  FIG. 9 . After the excess slurry  900  is reversed out the service string  500  can close opened flow control devices  124  of the “lower” sand completion system  100  and the second port closure sleeve  432 , thereby, isolating the “lower” hydrocarbon bearing zone  610 . 
     As depicted in  FIG. 10 , the service string  500  can actuate or “open” at least the lower flow control device  124  of the “upper” sand completion system  100  and the first port closure sleeve  430 . Then the service string can be aligned with the port closure sleeve  430  using the position indicator  440 . Gravel Slurry  630  can be pumped into the annulus  620  adjacent the “upper” hydrocarbon bearing zone  605 . The gravel slurry can gather in the annulus  620 . As the gravel slurry  620  dehydrates the fluid portion  632  can migrate through the sand screen assemblies  110 ,  112  and the flowpaths  114 ,  116 ,  118  of the “upper” sand completion system  100 , and can flow through the opened flow control devices  124  into the completion bore  405  adjacent to the “upper” hydrocarbon bearing zone  605 . The fluid portion  632  can travel uphole as depicted in  FIG. 10 , and the gravel  634  is held in place by the screen assemblies  110 ,  112 . After the gravel pack is formed in the annulus  620  adjacent the “upper” hydrocarbon bearing zone  605 , the excess slurry  900  can be reversed out as depicted in  FIG. 11 . After the reverse out operation the opened flow control devices  124  and the first port closure sleeve  430  can be closed completely isolating the annulus  620  adjacent to each hydrocarbon bearing zone  605 ,  610 , and the service tool  500  can be removed, as depicted in  FIG. 12 . The above described actions can be performed for each hydrocarbon bearing zone intersected by the wellbore  600 . 
     In one or more embodiments, when the upper completion is landed and the surface installations are ready for production, the flow control devices  124  can be selectively opened using slickline, wireline, coil tubing, or another conventional method to provide access to the hydrocarbon bearing zones  605 ,  610 . In one or more embodiments, mechanical or magnetic interaction can be used to open the flow control devices  124 . 
     In one or more embodiments, the flow control device  124  can be operated remotely. For example, pressure or a control conduit disposed adjacent to the completion  400  can be used to operate the flow control devices  124 . The flow control devices  124  can also be operated remotely during the gravel pack operation as described in U.S. Pat. No. 6,446,729. 
     The present completion string and methods may be practiced in combination with one or more sets of components and/or service tools, including bridge plugs, flow valves, and other commonly used oil field tools. The term “attached” refers to both direct attachment and indirect attachment, such as when one or more tubulars or other downhole components are disposed between the “attached” components. 
     Certain embodiments and features have been described using a set of numerical upper limits and a set of numerical lower limits. It should be appreciated that ranges from any lower limit to any upper limit are contemplated unless otherwise indicated. Certain lower limits, upper limits and ranges appear in one or more claims below. All numerical values are “about” or “approximately” the indicated value, and take into account experimental error and variations that would be expected by a person having ordinary skill in the art. 
     Various terms have been defined above. To the extent a term used in a claim is not defined above, it should be given the broadest definition persons in the pertinent art have given that term as reflected in at least one printed publication or issued patent. Furthermore, all patents, test procedures, and other documents cited in this application are fully incorporated by reference to the extent such disclosure is not inconsistent with this application and for all jurisdictions in which such incorporation is permitted. 
     While the foregoing is directed to embodiments of the present invention, other and further embodiments of the invention may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.
Apparatus having a first outer tubular member and a first inner tubular member. The first outer tubular member and the first inner tubular member can define a first space therebetween. The first inner tubular member can have a first internal bore. The apparatus can further include a second outer tubular member and a second inner tubular member. The second outer tubular member and the second inner tubular member can define a second space therebetween. The second inner tubular member can have a second internal bore. A first coupling flowpath can be positioned between the first and second spaces. A second coupling flowpath can be positioned between the first and second internal bores. A selectively closeable flowpath can be positioned between the first coupling flowpath and the second coupling flowpath.