Patent Publication Number: US-10309192-B2

Title: One trip completion assembly system and method

Description:
PRIORITY 
     The present application is a U.S. National Stage patent application of International Application No. PCT/US2016/065350, filed on Dec. 7, 2016, which claims priority to U.S. Provisional Patent Application No. 62/266,868, filed Dec. 14, 2015, both entitled, “ONE TRIP COMPLETION ASSEMBLY SYSTEM AND METHOD,” and the disclosures of which are hereby incorporated by reference in their entirety. 
    
    
     TECHNICAL FIELD 
     The present disclosure relates generally to well completion and production operations and, more specifically, to running in and setting completion assemblies in a single trip. 
     BACKGROUND 
     In the process of completing an oil or gas well, the running in and setting of a completion assembly is typically a two trip procedure. The lower completion assembly is run in on a packer running tool. The lower completion assembly generally consists of a production packer/sand control packer and a screen assembly which together function as a flow regulating system. An inner tubing string is also hung off of the packer running tool and extends down to the bottom of the screen assembly. A circulation fluid is then pumped down the inner tubing string to the bottom of the screen assembly and back up the annulus between the lower completion assembly and the wellbore wall in order to displace formation, drilling and other fluids that may be present in the wellbore. Following circulation, the packer is set and the running tool with the inner string is retrieved from the wellbore. Thereafter, the upper completion assembly is run-in. Just after coupling the upper completion assembly to the lower completion assembly, a circulation fluid is pumped down through the upper completion assembly to displace any fluids that may be in the wellbore above the location of the packer. 
     Typically, the screen assembly consists of a base pipe wrapped with a filter, which may be in the form of a generally cylindrical screen. The screen has a multiplicity of entry points through which produced fluid (liquid and/or gas) passes through the screen to apertures formed in the base pipe. The base pipe, in turn, is in fluid communication with production tubing extending from the surface, thus permitting the produced fluids to flow to the surface. In some cases, the screen assembly may include an inflow control device (ICD) positioned adjacent to or in proximity to the screen. The ICD regulates the flow of the produced fluid to the base pipe apertures after the produced fluid passes through an entry point of the screen. 
     It would be desirable to provide a method for installing an entire single completion assembly in a single trip during which various fluids in the wellbore can be displaced by circulation. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       Various embodiments of the present disclosure will be understood more fully from the detailed description given below and from the accompanying drawings of various embodiments of the disclosure. In the drawings, like reference numbers may indicate identical or functionally similar elements. 
         FIG. 1  is a schematic illustration of an offshore oil and gas platform operably coupled to a production string consisting of upper and lower production assemblies according to an embodiment of the present disclosure; 
         FIG. 2  illustrates a side view of a lower production assembly, according to an exemplary embodiment of the present disclosure; 
         FIG. 3  illustrates a partial cross sectional view of a screen assembly and flow regulating system of a lower production assembly, according to an exemplary embodiment of the present disclosure; 
         FIG. 4  illustrates a partial cross sectional view of the lower production assembly of  FIG. 3 , but with dissolvable material installed, according to an exemplary embodiment of the present disclosure; 
         FIGS. 5A-5E  illustrate the production string of the disclosure deployed in a wellbore; 
         FIG. 6  illustrates a method of installing production string, according to an exemplary embodiment of the present disclosure; and 
         FIG. 7  illustrates a method of installing production string, according to an exemplary embodiment of the present disclosure. 
     
    
    
     DETAILED DESCRIPTION 
     The disclosure may repeat reference numerals and/or letters in the various examples or figures. This repetition is for the purpose of simplicity and clarity and does not in itself dictate a relationship between the various embodiments and/or configurations discussed. Further, spatially relative terms, such as beneath, below, lower, above, upper, uphole, downhole, upstream, downstream, and the like, may be used herein for ease of description to describe one element or feature&#39;s relationship to another element(s) or feature(s) as illustrated, the upward direction being toward the top of the corresponding figure and the downward direction being toward the bottom of the corresponding figure, the uphole direction being toward the surface of the wellbore, the downhole direction being toward the toe of the wellbore. Unless otherwise stated, the spatially relative terms are intended to encompass different orientations of the apparatus in use or operation in addition to the orientation depicted in the figures. For example, if an apparatus in the figures is turned over, elements described as being “below” or “beneath” other elements or features would then be oriented “above” the other elements or features. Thus, the exemplary term “below” can encompass both an orientation of above and below. The apparatus may be otherwise oriented (rotated 90 degrees or at other orientations) and the spatially relative descriptors used herein may likewise be interpreted accordingly. 
     Moreover even though a figure may depict a horizontal wellbore or a vertical wellbore, unless indicated otherwise, it should be understood by those skilled in the art that the apparatus according to the present disclosure is equally well suited for use in wellbores having other orientations including vertical wellbores, deviated wellbores, multilateral wellbores or the like. Likewise, unless otherwise noted, even though a figure may depict an offshore operation, it should be understood by those skilled in the art that the apparatus according to the present disclosure is equally well suited for use in onshore operations and vice-versa. Further, unless otherwise noted, even though a figure may depict a cased hole, it should be understood by those skilled in the art that the apparatus according to the present disclosure is equally well suited for use in open hole operations. 
     Referring initially to  FIG. 1 , a production string  10  consisting of an upper portion and a lower portion is disposed as a single unit in a wellbore from an offshore oil or gas platform that is schematically illustrated and generally designated  11 . A semi-submersible platform  12  is positioned over a submerged oil and gas formation  14  located below a sea floor  16 . A subsea conduit  18  extends from a deck  20  of the platform  12  to a subsea wellhead installation  22 , including blowout preventers  24 . The platform  12  has a hoisting apparatus  26 , a derrick  28 , a travel block  30 , a hook  32 , and a swivel  34  for raising and lowering pipe strings, such as a substantially tubular, axially extending tubing string  36 . 
     A wellbore  38  extends through the various earth strata including the formation  14  and has a casing string  40  cemented therein. Production string  10  is illustrated positioned in a substantially horizontal portion of the wellbore  38 . Production string  10  includes a lower portion  42  having a distal end  43  and a proximal end  45 . Production string  10  also includes an upper portion  60  having a distal end  65  and a proximal end  67 . Spanning the upper portion  60  and lower portion  42  is a flow regulating system  48  which generally includes a an upper circulation valve  68 , a production packer  46 , a screen assembly  47  and a flow valve  53   a  positioned between the screen assembly  47  and the production packer  46 . Although generally not limited to a particular valve type, in one or more embodiments, as described below, flow valve  53   a  is an isolation barrier valve, while in other embodiments, as described below, flow valve  53   a  is a circulation valve. The production packer  46  may be positioned adjacent the proximal end  45  of the lower portion  42 , while the upper circulation valve  68  may be positioned adjacent the distal end  65  of the upper portion  60  so as to be in proximity to the production packer  46 . Lower portion  42  may also include additional screen assemblies  47  and additional packers, such as packer  50  or packer  54 . In one or more preferred embodiments, lower portion  42  may include a ball seat  49 , a packer  58  and a float shoe  61 . In embodiments, packer  58  may be a flow around packer. Finally, lower portion  42  may include various other components, such as a latch subassembly  44 . 
     Production string  10  is disposed in the wellbore  38  at the lower end of the tubing string  36  so as to form an annulus  75  between the production string  10  and casing string  40  or the production string  10  and the wall of wellbore  38  in instances where wellbore  38  is not cased. Upper portion  60  includes at least one upper circulation valve or fluid flow control module  68 , such as a circulating valve, and may further include various components such as a packer  62 , an expansion joint  64 , a packer  66  and an anchor assembly  70 . Upper circulation valve  68  may be selectively operated to establish flow from the interior flow passage  78  of production string  10  to annulus  75  during circulating operations. In one or more embodiments, valve  68  may be a remotely controlled circulating valve. Valve  68  may be driven between a first closed position and a second open position. In one or more embodiments, during run-in of production string  10 , valve  68  is set in the first closed position. Once production string  10  has been deployed and the lower portion  42  has been circulated as described below, valve  68  may be actuated to an open position to allow circulation of upper portion  60 . In one or more embodiments, a control line, such as a tubing or conduit, may extend down to valve  68  and may be utilized to control valve  68 . In this regard, valve  68  may be a dual (balanced) control line circulating valve for circulating above packer  46 . 
     Upper portion  60  may also include a latch subassembly  72 . One or more communication cables such as an electric cable  74  that passes through the packers  62 ,  66  may be provided and extend from the upper portion  60  to the surface in an annulus  75  between the tubing string  36  and the casing  40 . The latch subassembly  44  couples to the latch subassembly  72  so upper portion  60  and lower portion  42  when joined together form a production string  10 . It will be appreciated that in one or more embodiments, because upper portion  60  and lower portion  42  are made up together and run-in together, the need for latch subassemblies  44  and  72  during installation of production string  10  is obviated, and in this regard, latch subassemblies  44 ,  72  may be omitted. However, it may still be desirable to detach upper portion  60  from lower portion  42  at some point after installation of production string  10 , and thus, in some embodiments, latch subassemblies  44 ,  72  are retained. 
     Also, even though  FIG. 1  depicts an offshore operation, it should be understood by those skilled in the art that the apparatus according to the present disclosure is equally well suited for use in onshore operations. Further, even though  FIG. 1  depicts a cased hole completion, it should be understood by those skilled in the art that the apparatus according to the present disclosure is equally well suited for use in open hole completions. In one or more embodiments, upper portion  60  may be deployed in a cased portion of wellbore  38 , while lower portion  42  may extend into an uncased portion of wellbore  38 . 
       FIG. 2  illustrates certain components of flow regulating system  48  generally encompassed by lower portion  42 . Along lower portion  42 , flow regulating system  48  restricts fluid communication between the annulus  75  and the interior flow passage  78  of the tubular string  36  adjacent the screen assembly  47  during run-in and [flow down] operations. As shown, the annulus  75  is formed radially between the tubular string  36  and the wellbore  38 , either uncased or (as shown) lined with the casing string  40  and cement  84 . During [flow down] operation, fluid  76  is pumped down interior flow passage  78  and out into the annulus  75  at a point below screen assembly  47 . In one or more embodiments, fluid  76  flows past packer  58  and out float shoe  43  (see  FIG. 1 ). Formation fluid  76  may also flow into annulus  75  from formation  14 . During installation of production string  10  and during flow down operations, packer  46  is retained in a retracted position so that fluid  76  can flow by packer  46  in order to clear debris from annulus  75 . It will be appreciated that once flow down operations are complete, packer  46  may be actuated to isolate the production zone from the annulus  75  above packer  46 . In one or more embodiments, packer  46  may be a production packer. In one or more embodiments, packer  46  may be a pass through packer to allow cables and control lines to pas to lower portions of the production assembly  10 . In addition to production packer  46 , one or more additional packers, such as packer  50  may be deployed along lower portion  42  to isolate production zones and/or provide stability to uncased wellbore walls. Packer  50  may be a swell packer. In one or more embodiments, packer  46  may be a control line set production packer. In addition to packer  46 , a lower circulation valve  53   a  is illustrated. It will be appreciated that lower circulation valve  53   a  may be selectively operated to control flow of fluid  76  along passage  78 , and in particular, to allow fluid communication between the lower portion  42  of production string  10  and the upper portion  60  of production string  10 . In one or more embodiments, valve  53   a  may be an isolation barrier valve. In one or more embodiments, valve  53   a  may be a circulation valve. In some embodiments, valve  53   a  may be remotely actuated, such as through the transmission of an acoustic signal, while in other embodiments, a control line running from platform  11  may be utilized to actuate valve  53   a . Valve  53   a  may be driven between a first open position and a second closed position. In one or more embodiments, during run-in of production string  10 , valve  53   a  is set in the first open position to allow wellbore fluids to pass into interior flow passage  78 . In one or more embodiments, valve  53   a  is a ball valve. Valve  53   a  may be controlled by a dual (balanced) control line. In such case, packer  46  may be a feed/pass through packer. 
     Screen assembly  47  generally includes a screen  85 . In some embodiments, screen assembly  47  may also include an inflow control device (ICD)  87 . Generally, during production, screen  85  prevents or at least reduces the amount of debris, such as gravel, sand, and other particulate matter, from entering the interior flow passage  78 . In one or more embodiments, the fluid  76  passing through the screen  85  then flows through the ICD  87  and into the interior flow passage  78  for eventual production to the surface, while in other embodiments, the fluid  76  passing through the screen  85  may flow along a defined flow path directly to the interior flow passage  78 . 
       FIG. 3  illustrates a more detailed partial cross sectional view of the flow regulating system  48 , and in particular screen assembly  47  according to an exemplary embodiment. In one or more embodiments, the screen  85  of the flow regulating system  48  is a filter formed of wire  86  and disposed on an inner tubular member or base pipe  90 . In one or more embodiments, screen  85  may be a swell screen. In one or more embodiments, the base pipe  90  is an elongated tubular member. Preferably, the wire  86  is wound or wrapped onto the base pipe  90  to form the screen  85 . In other embodiments, screen  85  may be a wire or synthetic mesh. In one or more embodiments, the screen  85  is an elongated tubular member and is disposed on the base pipe  90  so as define an exterior flow path or passage  88  between the screen  85  and the base pipe  90 . In one or more embodiments, gaps between the wires  86  form openings or entry points  91 , through which the fluid  76  passes through the screen  85 . The passage  88  may be defined utilizing standoff supports (not shown) arranged in parallel, and circumferentially spaced around the exterior surface of the base pipe  90  to support the screen  85  in a spaced apart arrangement from the base pipe  90 . The passage  88  may also be defined between one or more adjacent screens  85  laid over one another or may be defined by the screen  85  itself. In any event, the passage  88  is formed to direct flow towards the interior flow passage  78 , which is defined within the base pipe  90 . 
     In one or more embodiments of flow regulating system  48  where an ICD  87  is included, the flow regulating system  48  may further include an interface ring  94  disposed about the exterior surface of the screen  85  to secure the screen  85  to the base pipe  90 . In one or more embodiments, the interface ring  94  may be secured using a “shrink fit” to secure the screen  85  to the base pipe  90 . A sleeve  96  is disposed in proximity to and/or about the exterior surface of the base pipe  90  defines a portion of the passage  88 . In some embodiments, the sleeve  96  is supported by the interface ring  94 . The ICD  87  is disposed adjacent or in proximity to the screen  85  along the base pipe  90 , preferably concentrically disposed about the exterior surface of the base pipe  90 . In an exemplary embodiment, the ICD  87  is configured to be coupled to the sleeve  96 . In an exemplary embodiment, the ICD  87  includes one or more tubular structures  100 , which restrict the flow of the fluid  76  from the passage  88  to an annular chamber  102  of ICD  87 . Although only one of the tubular structures  100  is visible in  FIG. 3 , a series of the tubular structures  100  may be arranged in parallel, and circumferentially spaced apart within the ICD  87 . The tubular structures  100  are one example of flow restrictors which may be used in the ICD  87 . In an exemplary embodiment, other types of flow restrictors may be used, such as for example chokes, orifices, nozzles, etc. Any type of flow restrictor may be used in keeping with the scope of this disclosure. In an exemplary embodiment, the fluid  76  flows through the tubular structures  100  to the annular chamber  102 . Thus, the tubular structures  100  provide for parallel flow of the fluid  76  from the passage  88  to the annular chamber  102 . The fluid  76  flows from the chamber  102  and then inward via openings  104  in the base pipe  90  to the interior flow passage  78 . The openings  104  are formed radially through the base pipe  90 , which is configured (e.g., with threads at either end, etc.) for interconnection in the tubular string  36 . Persons of skill in the art will appreciate that while ICD  87  is described in some embodiments of screen assembly  47 , in other embodiments of screen assembly  47 , an ICD  87  need not be included. For example, the base pipe  90  may be provided with the openings  104 . The screen  85  having the shroud  92  overlays the base pipe  90 . The screen  85  is longitudinally spaced apart from the openings  104  so the passage  88  extends longitudinally between the openings  91  of the screen  85  and the openings  104  to guide the fluid  76  flowing through the screen  85  to the openings  104 . 
       FIG. 4  illustrates a partial cross sectional view of the flow regulating system  48  and screen assembly  47  of  FIG. 3 , but with dissolvable material  92  installed to block flow into interior flow passage  78  of base pipe  90 . In one or more embodiments, dissolvable material  92  is deployed in the openings or entry points  91  of screen  85 , as shown by dissolvable material  92   a . In one or more embodiments, dissolvable material  92  is deployed in passage  88  in the form of a plug, as shown by dissolvable material  92   b . In one or more embodiments, dissolvable material  92  is deployed in chamber  102  in the form of a plug, as shown by dissolvable material  92   c . Finally, in one or more embodiments, dissolvable material  92  in the form of a shroud may be placed over screen  85 , as shown by dissolvable material  92   d . For illustrative purposes, shroud  92   d  is only covering a portion of screen  85 , but it will be appreciated that in one or more embodiments, dissolvable shroud  92   d  will fully cover screen  85  and the openings  91  formed therein. In other embodiments, the dissolvable material  92  may be deployed in various combinations, such as a portion of the material  92   a  disposed in the openings  91 , and another portion of material  92   d  covering a portion of the screen  85 . Persons of ordinary skill in the art will appreciate that dissolvable material  92  may be deployed anywhere along the fluid flow path that passes through flow regulating system  48  so long as fluid communication into interior flow passage  78  of base pipe  90  is temporarily block during one-trip run-in and deployment of production string  10 . 
     Dissolvable material  92  may be any material that can be readily removed chemically or mechanically to establish flow through flow regulating system  48 . In one or more embodiments, dissolvable material  92  may be a material that can be chemically removed by dissolving the material in the presence of a fluid, such as a wellbore fluid or breaker fluid, once run-in and deployment are complete. 
     In other embodiments of flow regulating system  48 , dissolvable material  92  may be replaced with a mechanical sleeve or valve disposed along base pipe  90  or otherwise adjacent screen  85  that may be actuated to prevent flow through the screen assembly as described herein. It will be appreciated that by incorporating dissolvable material  92  into the screen openings  91  or as otherwise described herein, or by otherwise blocking flow through flow regulating system  48 , flow regulating system  48  effectively can function as a solid pipe (such as during run-in and flow down operations) until the dissolvable material is removed. As such, the need for an inner string during run-in is avoided, and hence, the need for an additional trip to pull the inner string out of the wellbore before tripping in the upper completion assembly is obviated. 
       FIGS. 5A-5E  illustrate various embodiments of production string  10  having a flow regulating system  48  as described herein. It will be appreciated that the production string  10  having a flow regulating system  48  may be utilized with a variety of other components, none of which are intended to be limiting. Thus, in  FIG. 5A , various possible components of a production string  10 , and in particular, an upper portion  60  thereof, are illustrated. Production string  10  may include one or more of a safety valve  81 , a gas lift mandrel  83 , a downhole gauge system  89  and a chemical injection system  93  carried by tubing string  36 . Continuing down the upper portion  60 , as best seen in  FIG. 5B , production string  10  includes an upper circulation valve  68 , which upper circulation valve  68  forms part of flow regulating system  48 . In one or more embodiments, upper circulation valve  68  may be remotely actuated, such as through the transmission of an acoustic signal, while in other embodiments, a control line running from platform  11  may be utilized to actuate upper circulation valve  68 . In one or more embodiments, upper circulation valve  68  is non-shrouded. In one or more embodiments, upper circulation valve  68  may be deployed adjacent the distal end  65  of upper portion  60 . It will be appreciated that when deployed adjacent the distal end  65 , and more specifically, adjacent packer  46 , then flow down operations for cleaning debris from annulus  75  are most effective. In any event, in  FIG. 5B , below upper circulation valve  68  is packer  46 . In one or more embodiments, packer  46  is a production packer that may be retrievable. In one or more embodiments, packer  46  is a pass-through packer, thereby allowing communication lines and cables to extend below packer  46 . Moreover, packer  46  may be actuated remotely by pressuring up the interior of string  36 . While various methods may be utilized to apply pressure to packer  46  to actuate packer  46  and deploy it, in one or more embodiments, an object (not shown) such as a ball or dart may be released into the wellbore  38  and seated on seat  49  ( FIG. 5D ). In other embodiments, valve  53   a  may be closed. In any event, a nipple  95  may be deployed along string  36 . 
     In one or more embodiments, a basket  97  may be provided upstream of packer  46  to catch debris in annulus  75  that would otherwise collect around packer  46 . Basket  97  may be retrievable. Basket  97  may include openings  99  to allow fluid to pass therethrough, while filtering out debris that could otherwise collect around packer  46 . 
     Continuing down production string  10 , in  FIG. 5C  and alternatively, in  FIG. 5E , valve  53   a  is illustrated. To the extent production string  10  is deployed at least partially in an open hole, valve  53   a  is preferably positioned within the cased portion of wellbore  38  as illustrated. Regardless of its type, valve  53   a  may be remotely actuated, such as through the transmission of an acoustic signal, while in other embodiments, a control line (not shown) running from platform  11  may be utilized to actuate valve  53   a . In these embodiments, packer  46  preferably is a pass-through packer to allow the control lines (not shown) to extend to valve  53   a . In one or more embodiments such as is shown in  FIG. 5C , valve  53   a  is an isolation barrier valve, while in other embodiments such as is shown in  FIG. 5E , valve  53   a  is a circulation valve. Circulation valve  53   a  as shown in  FIG. 5E  may include a shroud  79 . 
     Below valve  53   a  is a screen assembly  47 . In one or more embodiments, screen assembly  47  may include dissolvable material  92  to inhibit flow through screen  85  or otherwise, to inhibit flow through openings  104  ( FIG. 4 ). In one or more embodiments where valve  53   a  is an isolation barrier valve, screen assembly  47  may include a screen  85  with dissolvable material  92  disposed in entry points  91  ( FIG. 4 ). In such embodiments, screen  85  may be a swell screen. Likewise, in one or more embodiments where valve  53   a  is a shrouded circulation valve, screen assembly  47  may include a convention screen  85  without dissolvable material  92 . In one or more embodiments, a plurality of spaced apart screen assemblies  47  may be provided below valve  53   a.    
     As illustrated in  FIG. 5D , below screen assembly  47 , in one or more embodiments, additional packers  50 ,  54  may be provided. The packers  50 ,  54  may be swell packers. The packers  50 ,  54  may be utilized to isolate production zones and/or provide stability to wellbore  38 . In one or more embodiments, a seat  49  may be provided for receipt of a releasable object (not shown) dropped or pumped down the well to allow the pressure upstream of the seat  49  to be increased by landing an object on the seat  49  as is well known in the industry. Seat  49  may be a ball seat and the object may be a ball. Below seat  49 , a flow around sub  58  with a packer may be provided. Finally, below sub  58 , at distal end  43  of lower portion  42 , a float shoe  61  may be provided. As described above, fluid  76  may be pumped down interior  78  of production string  10  and out into annulus  75 . 
     Persons of ordinary skill in the art will appreciate that the descriptions of production string  10  as having upper and lower portions is not intended to be limiting, but is simply included to establish the relative axial positioning of components of the flow regulating system  48 . 
     In an exemplary embodiment and as illustrated in  FIG. 6  with continuing reference to  FIGS. 1-5 , a method  200  of installing production string  10  is described. In a first step  202 , a production string  10  having an upper completion portion  60  and a lower completion portion  42  is run together into a wellbore  38 . The production string  10  is made up prior to running the production string into the wellbore  38 . As part of the lower completion portion  42 , the production string  10  includes at least one screen assembly  47 , at least one packer  46  and at least one lower valve  53   a . The lower valve  53   a  is positioned below the packer  46  so that the valve can be actuated to allow fluid in the interior of production string  10  to flow to the distal end  43  of the lower completion portion  42 , and then out into the annulus  75 . The lower valve  53   a  may be a remotely controlled isolation barrier valve. The lower valve  53   a  is set into a first open position during run-in. The screen assembly  47  is configured to prevent fluids from flowing therethrough, i.e., through the screen  85  and into the interior of the base pipe  90 . This configuration may include a dissolvable material  92  deployed along a flow path  88  of the screen assembly  47  to prevent flow of fluid through the screen assembly, i.e., from the annulus  75  to the interior of base pipe  90 . In other embodiments, this configuration may include a mechanical sleeve or valve that may be actuated to prevent flow through the screen assembly. Such actuation may be remotely accomplished through application of a fluid pressure or from a signal transmitted thereto. 
     As part of the upper completion portion  60 , the production string  10  includes at least one upper valve  68 . Upper valve  68  may be a circulation valve. In one or more embodiments, circulation valve  68  is not shrouded. The upper circulation valve  68  is set into a first closed position during run-in. The upper circulation valve  68  may be a remotely controlled isolation barrier valve. In any event, the production string  36  is run-in the wellbore  38  to the desired position. Positioning may be accomplished by running the production string in a tubing string until a desired point is reached, at which point a tubing hanger may be attached to the tubing string. Thereafter, the tubing hanger may be landed on a tubing head spool to position the production string. It will be appreciated that the disclosure is not limited to the manner of positioning of the production string so long as the production string includes both the upper and lower completion assemblies so as to avoid the need for a second trip in. 
     It will be appreciated that in one or more embodiments, production string  10  may further include a seat  49  and a float shoe  61  below screen assembly  47 . Likewise, production string  10  may include a flow around sub  58  adjacent float shoe  61 . 
     In step  204 , once the production string  10  is positioned, fluid is circulated down the production string and into the annulus  75  surrounding the lower completion assembly. In particular, the fluid is circulated down through the lower completion portion  42  and is introduced in the annulus  75  below the screen assembly  47  of the lower completion portion  42 . Because the flow path through the screen assembly is blocked, the circulating fluid passes axially through the annulus or inner passage of the lower completion portion as if it were a solid pipe. Flow from the lower completion portion  42  is then directed into the annulus  75 , where the flow travels up through the annulus to the surface. It will be appreciated that during this step  204 , production packer  46  has not been activated. As such, fluid can flow in annulus  75  past production packer  46  to the surface to flush annulus  75 . 
     In step  206 , flow through the screen  85  and into the base pipe  90  is enabled. In some embodiments, this may be accomplished by circulating a fluid down the production string  10  and into contact with a dissolvable material  92  of the lower completion assembly. In some embodiments, this may be accomplished by actuating a sleeve  92  or valve adjacent the base pipe  90  to permit fluid to flow through the screen  85  and into the interior of the base pipe  90 . To the extent dissolvable material  92  is utilized to inhibit flow therebetween, the fluid may be a breaker fluid that chemically interacts with the dissolvable material. In one or more embodiments, a material disposed in the openings of the screen  85  is dissolved utilizing the fluid to permit fluid flow through the screen. In one or more embodiments, a plug  92   a  disposed in the openings of the screen  85  or along a flow channel  88  of the lower completion assembly  42  is dissolved utilizing the fluid to permit fluid flow through the screen  85  and into the base pipe  90 . In one or more embodiments, the fluid may be the same fluid utilized during the circulating step  204 , in which case, the dissolvable material  92  begins to dissolve during step  204  so that upon completion of step  204 , or following a period of time thereafter, the dissolvable material has been dissolved and flow through the screen and into the base pipe is enabled. 
     In step  208 , the lower circulation valve  53   a  is actuated to move from first open position to second closed position. This actuation may be accomplished remotely. Remote operation may occur utilizing a signal, such as an electrical, optic or acoustic pulse transmitted from the surface or otherwise, locally transmitted from a signal source in the vicinity of the valve. In one or more embodiments, such actuation may be accomplished utilizing a fluid pressure or a pressure differential. In one or more embodiments, such actuation may be accomplished utilizing a timer activated valve, such that the valve would actuate after a period of time t following a given action, such as deployment. In one or more embodiments, the lower circulation valve may include a differential trigger mechanism to cycle open or closed when a particular low or high pressure threshold is reached. It will be appreciated that by closing valve  53   a , the lower completion portion  42 , and in particular, fluid  76  flowing from the formation into the lower completion portion  42 , is isolated from the upper completion portion  60 . 
     In step  210 , the production packer  46  located above the lower circulation valve  53   a  is set. Packer  46  may be set utilizing any known techniques. In one or more embodiments, packer  46  may be set by releasing a ball, dart or similar releasable object in order to apply a setting pressure to the packer  46 . In one or more embodiments, the packer  46  may be set by closing all valves and applying a setting pressure to the packer  46 . This may be utilized in conjunction with the aforementioned releasable object. It will be appreciated that in cases where packer  46  is activated utilizing a seat, such as seat  49 , that is below valve  53   a , then valve  53   a  will remain open until after packer  46  is set. Alternatively, valve  53   a  may be closed to apply a setting pressure to packer  46 . 
     In step  212 , the upper circulation valve  68  is actuated to move from the first closed position to the second open position. This actuation may be accomplished remotely. Remote operation may occur utilizing a signal, such as an electrical, optic or acoustic pulse transmitted from the surface or otherwise, locally transmitted from a signal source in the vicinity of the valve. In one or more embodiments, such actuation may be accomplished utilizing a fluid pressure or a pressure differential. In one or more embodiments, such actuation may be accomplished utilizing timer activated valve, such that the valve would actuate after a period of time t following a given action, such as deployment. In one or more embodiments, the upper circulation valve may include a differential trigger mechanism to cycle open or closed when a particular low or high pressure threshold is reached. 
     In step  214 , with the upper circulation valve  68  open, the annulus  75  above packer  46  is circulated to displace wellbore fluid in the annulus. In this step, it will be appreciated that lower circulation valve  53   a  is closed, such that a circulation fluid pumped down through the upper completion assembly will be directed out into the annulus  75  about the upper completion portion  60 . In one or more embodiments, the circulation fluid pumped down in this step  214  may be brine or any other fluid utilized for such purpose. 
     In step  216 , once circulation in the upper portion of the wellbore, i.e., above packer  46 , is complete, upper circulation valve  68  is actuated from the second open position back to the first closed position. This actuation may be accomplished as described above. 
     Once step  216  is complete, the well may thereafter be produced as is well known in the art. 
     In one or more embodiments, additional procedures may be performed to ensure that the production string has been deployed as desired. Thus, in a step  218 , pressure may be applied internally to the production string  10  to a threshold pressure to ensure string integrity. Likewise, annular pressure may be increased to a threshold pressure to ensure desired operation of the packer. Thereafter, the tubing pressure and annular pressure may be bled off. In step  220 , the lower circulation valve  53   a  may be actuated from a second closed position to a first open position. 
     In an exemplary embodiment and as illustrated in  FIG. 7  with continuing reference to  FIGS. 1-5 , a method  300  of installing production string  10  is described. In a first step  302 , a production string  10  having an upper completion portion  60  and a lower completion portion  42  is run together into a wellbore  38 . The production string  10  is made up prior to running the production string into the wellbore  38 . As part of the lower completion portion  42 , the production string  10  includes at least one screen assembly  47 , at least one packer  46  and at least one lower valve  53   a . In some embodiments, valve  53   a  is a circulation valve. In one or more embodiments where valve  53   a  is a circulation valve, circulation valve  53   a  is shrouded. In one or more embodiments, the lower circulation valve  53   a  is positioned below the packer  46  so that the valve can be actuated to control flow of fluid through the production string  10  to the lower completion portion  42 . The lower circulation valve  53   a  may be a remotely controlled circulating valve. In one or more embodiments, lower circulation valve  53   a  is set in a closed position during run-in. The screen assembly  47  is configured to prevent fluids from flowing therethrough, i.e., through the screen  85  and into the interior of the base pipe  90 . This configuration may include a dissolvable material  92  deployed along a flow path  88  of the screen assembly  47  to prevent flow of fluid through the screen assembly, i.e., from the annulus  75  to the interior of base pipe  90 . In other embodiments, this configuration may include a mechanical sleeve or valve that may be actuated to prevent flow through the screen assembly. Such actuation may be remotely accomplished through application of a fluid pressure or from a signal transmitted thereto. 
     As part of the upper completion portion  60 , the production string  10  includes at least one upper circulation valve  68 . The upper circulation valve  68  may be a remotely controlled circulating valve. The upper circulation valve  68  is set in a closed position during run-in. In any event, the production string  10  is run-in the wellbore to the desired position. Positioning may be accomplished by running the production string in a tubing string until a desired point is reached, at which point a tubing hanger may be attached to the tubing string. Thereafter, the tubing hanger may be landed on a tubing head spool to position the production string. It will be appreciated that the disclosure is not limited to the manner of positioning of the production string so long as the production string includes both the upper and lower completion portions so as to avoid the need for a second trip in for installing the production string. 
     It will be appreciated that in one or more embodiments, production string  10  may further include a seat  49  and a float shoe  61  below screen assembly  47 . Likewise, production string  10  may include a flow around sub  58  adjacent float shoe  61 . Additionally, in this embodiment, an absolute isolation string (AIS) is preferably included below the conventional screen assembly. 
     In step  304 , once the production string  10  is positioned, fluid is circulated down the production string and into the annulus  75  surrounding the lower completion portion  42 . In particular, the fluid is circulated down through the lower completion portion  42  and is introduced in the annulus  75  below the screen assembly  47  of the lower completion portion  42 . Because the flow path through the screen assembly is blocked, the circulating fluid passes axially through the annulus or inner passage of the lower completion assembly as if it were a solid pipe. Flow from the lower completion portion  42  is then directed into the annulus  75 , where the flow travels up through the annulus to the valve  53   a , as which point, valve  53   a  directs the flow along a desired flowpath. In one more embodiments, a shroud  79  of valve  53   a  is utilized to direct flow into the interior of the production string. 
     In step  306 , flow through the screen  85  and into the base pipe  90  is enabled. In some embodiments, this may be accomplished by circulating a fluid down the production string  10  and into contact with a dissolvable material  92  of the lower completion assembly. In some embodiments, this may be accomplished by actuating a sleeve  92  or valve adjacent the base pipe  90  to permit fluid to flow through the screen  85  and into the interior of the base pipe  90 . To the extent dissolvable material  92  is utilized to inhibit flow therebetween, the fluid may be a breaker fluid that chemically interacts with the dissolvable material. In one or more embodiments, a material disposed in the openings of the screen  85  is dissolved utilizing the fluid to permit fluid flow through the screen. In one or more embodiments, a plug  92   a  disposed in the openings of the screen  85  or along a flow channel  88  of the lower completion assembly  42  is dissolved utilizing the fluid to permit fluid flow through the screen  85  and into the base pipe  90 . In one or more embodiments, the fluid may be the same fluid utilized during the circulating step  304 , in which case, the dissolvable material  92  begins to dissolve during step  304  so that upon completion of step  304 , or following a period of time thereafter, the dissolvable material has been dissolved and flow through the screen and into the base pipe is enabled. 
     In step  310 , the production packer  46  located above the lower circulation valve  53   a  is set. Packer  46  may be set utilizing any known techniques. In one or more embodiments, packer  46  may be set by releasing a ball, dart or similar releasable object in order to apply a setting pressure to the packer  46 . In one or more embodiments, the packer  46  may be set by closing all valves and applying a setting pressure to the packer  46 . This may be utilized in conjunction with the aforementioned releasable object. It will be appreciated that in cases where packer  46  is activated utilizing a seat, such as seat  49 , that is below valve  53   a , then valve  53   a  will remain open until after packer  46  is set. Alternatively, valve  53   a  may be closed in order to apply a setting pressure to packer  46 . 
     In step  312 , the upper circulation valve  68  is actuated to move from the first closed position to the second open position. This actuation may be accomplished remotely. Remote operation may occur utilizing a signal, such as an electrical, optic or acoustic pulse transmitted from the surface or otherwise, locally transmitted from a signal source in the vicinity of the valve. In one or more embodiments, such actuation may be accomplished utilizing a fluid pressure or a pressure differential. In one or more embodiments, such actuation may be accomplished utilizing timer activated valve, such that the valve would actuate after a period of time t following a given action, such as deployment. In one or more embodiments, the upper circulation valve may include a differential trigger mechanism to cycle open or closed when a particular low or high pressure threshold is reached. 
     In step  314 , with the upper circulation valve  68  open, the annulus  75  above packer  46  is circulated to displace wellbore fluid in the annulus. In this step, it will be appreciated that lower circulation valve  53   a  is closed, such that a circulation fluid pumped down through the upper completion assembly will be directed out into the annulus  75  about the upper completion portion  60 . In one or more embodiments, the circulation fluid pumped down in this step  214  may be brine or any other fluid utilized for such purpose. 
     In step  316 , once circulation in the upper portion of the wellbore, i.e., above packer  46 , is complete, upper circulation valve  68  is actuated from the second open position back to the first closed position. This actuation may be accomplished as described above. 
     Once step  316  is complete, the well may thereafter be produced as is well known in the art. 
     In one or more embodiments, additional procedures may be performed to ensure that the production string has been deployed as desired. Thus, in a step  318 , pressure may be applied internally to the production string  10  to a threshold pressure to ensure string integrity. Likewise, annular pressure may be increased to a threshold pressure to ensure desired operation of the packer. Thereafter, the tubing pressure and annular pressure may be bled off. In step  320 , the lower circulation valve  53   a  may be actuated from a second closed position to a first open position. 
     Thus, a method for installing a production string in a wellbore has been described. The method may generally include deploying a lower completion portion and an upper completion portion together into a wellbore at the same time; circulating fluid down through the lower completion portion and into the wellbore annulus adjacent the lower completion portion; following the step of circulating through the lower completion portion, enabling flow through a screen and into a base pipe of the lower completion portion; actuating a lower circulation valve to move the lower circulation valve from a first open position to a second closed position; setting a packer positioned above the lower circulation valve; actuating an upper circulation valve to move the upper circulation valve from a first closed position to a second open position; with the upper circulation valve in the second open position, circulating fluid down through the upper completion portion and into the wellbore annulus above the packer; and following the step of circulating through the upper completion portion, actuating the upper circulation valve to move the upper circulation valve from the second open position to the first closed position. Likewise, a method for installing a production string in a wellbore may generally include deploying a lower completion portion and an upper completion portion together into a wellbore at the same time; circulating fluid down through the lower completion portion and into the wellbore annulus adjacent the lower completion portion; following the step of circulating through the lower completion portion, enabling flow through a screen and into a base pipe of the lower completion portion; setting a packer positioned above a lower circulation valve; actuating an upper circulation valve to move the upper circulation valve from a closed position to an open position; with the upper circulation valve in the open position, circulating fluid down through the upper completion portion and into the wellbore annulus above the packer; and following the step of circulating through the upper completion portion, actuating the upper circulation valve to move the upper circulation valve from the open position to the closed position. 
     For the foregoing embodiments, the method may include any one of the following steps, alone or in combination with each other: 
     Producing hydrocarbons from the wellbore once the step of circulating the upper completion portion is complete. 
     Circulating fluid through the lower completion portion comprises blocking the circulating flow from passing through a screen and into the lower completion portion. 
     The deploying step comprises configuring, prior to run-in, the upper completion portion to have the upper circulation valve in the first closed position above the packer and configuring, prior to run-in, the lower completion portion to have the lower circulation valve in the first open position below the packer in the production string. 
     Increasing internal pressure within the production string to a threshold pressure to ensure string integrity; increasing annular pressure to a threshold pressure to ensure desired operation of the packer; bleeding off the internal and annular applied pressures; and actuating the lower circulation valve from the second closed position to the first open position. 
     Producing hydrocarbons from the wellbore once the step of circulating the upper completion portion is complete. 
     The setting the packer step comprises releasing an object into the wellbore; landing the object at a location below the packer to inhibit flow past the packer; and increasing fluid pressure in the wellbore above the object to set the packer. 
     The setting the packer step comprises increasing fluid pressure in the wellbore while the upper circulation valve is in the first closed position and the lower circulation valve is in the second closed position; and utilizing the increase in fluid pressure to actuate the packer. 
     The circulating fluid through the lower completion portion step comprises blocking the circulating flow from passing through the screen and into the lower completion portion. 
     The deploying step comprises configuring, prior to run-in, the upper completion portion to have the upper circulation valve in the closed position above the packer and configuring, prior to run-in, the lower completion portion to have the lower circulation valve in a closed position below the packer in the production string. 
     Producing hydrocarbons from the wellbore once the step of circulating the upper completion portion is complete. 
     Increasing internal pressure within the production string to a threshold pressure to ensure string integrity; increasing annular pressure to a threshold pressure to ensure desired operation of the packer; bleeding off the internal and annular applied pressures; and actuating the lower circulation valve from a closed position to an open position. 
     The setting the packer step comprises releasing an object into the wellbore; landing the object at a location below the packer to inhibit flow past the packer; and increasing fluid pressure in the wellbore above the releasable object to set the packer. 
     The enabling flow through the screen and into the base pipe of the lower completion portion step comprises dissolving a plug blocking flow through the lower completion portion. 
     The dissolving step comprises dissolving a material in openings of the screen thereby permitting a fluid to flow through the screen. 
     The dissolving step comprises dissolving a material in a flow passage of the lower completion portion. 
     The dissolving step comprises dissolving a material covering openings of the screen thereby permitting a fluid to flow through the screen. 
     The lower circulation valve is actuated remotely by a signal from the surface. 
     The upper circulation valve is actuated remotely by a signal from the surface. 
     A production assembly for deployment in hydrocarbon recovery operations has been described. Embodiments of the assembly may generally include an upper completion portion comprising a tubular characterized by an interior and an exterior and an upper circulation valve movable between a closed position to block fluid communication between the interior and the exterior of the tubular and an open position to establish fluid communication between the interior and the exterior of the tubular; a lower completion portion attached to the upper completion portion, the lower completion portion comprising at least one screen assembly having a screen deployed adjacent a base pipe characterized by an interior and exterior with a flow path defined through the screen from the exterior to the interior of the base pipe, at least one packer and at least one lower circulation valve movable between an open position to establish fluid communication between the interior and the exterior of the base pipe and a closed position to block fluid communication between the interior and the exterior of the base pipe, the screen assembly further comprising a dissolvable material deployed along the flow path to prevent fluid flow along the flow path. Likewise, an assembly for deployment in a wellbore may generally include a plug deployed in a wellbore; a production string having an upper completion portion and a lower completion portion, wherein the lower completion portion is spaced apart from the plug; an upper completion portion comprising a tubular characterized by an interior and an exterior and an upper circulation valve movable between a closed position to block fluid communication between the interior and the exterior and an open position to establish fluid communication between the interior and the exterior of the tubular; a lower completion portion attached to the upper completion portion, the lower completion portion comprising at least one screen assembly having a screen deployed adjacent a base pipe characterized by an interior and exterior with a flow path defined through the screen from the exterior to the interior of the base pipe, at least one packer and at least one lower circulation valve movable between an open position to establish fluid communication between the interior and the exterior of the base pipe and a closed position to block fluid communication between the interior and the exterior of the base pipe, the screen assembly further comprising a dissolvable material deployed along the flow path to prevent fluid flow along the flow path. 
     For any of the foregoing embodiments, assembly may include any one of the following elements, alone or in combination with each other: 
     The screen comprises a multiplicity of openings, wherein the dissolvable material is deployed in the openings of the screen. 
     The upper circulation valve is a remotely controlled circulating valve and the lower circulation valve is a remotely controlled isolation barrier valve. 
     The dissolvable material is a dissolvable shroud deployed over the openings of the screen. 
     The foregoing description and figures are not drawn to scale, but rather are illustrated to describe various embodiments of the present disclosure in simplistic form. Although various embodiments and methods have been shown and described, the disclosure is not limited to such embodiments and methods and will be understood to include all modifications and variations as would be apparent to one skilled in the art. Therefore, it should be understood that the disclosure is not intended to be limited to the particular forms disclosed. Accordingly, the intention is to cover all modifications, equivalents and alternatives falling within the spirit and scope of the disclosure as defined by the appended claims.