Patent Publication Number: US-2023147546-A1

Title: Single trip wellbore completion system

Description:
BACKGROUND 
     The present document is based on and claims priority to U.S. Provisional Application Ser. No. 63/006,994, filed Apr. 8, 2020, which is incorporated herein by reference in its entirety. 
    
    
     Subterranean hydrocarbon services are often necessary to produce hydrocarbons from a subterranean formation. Such services can include, without limitation, perforating operations, completion operations, gravel pack operations, frac pack operations, clean-up operations, flow-back operations, treatment operations, testing operations, production operations, injection operations, and monitor and control operations. Each service is typically performed by running specially designed, service-specific equipment into and out of the wellbore. This is problematic because each trip into and out of the wellbore increases operational risks, rig time, and personnel hours. 
     While the repetitive steps of running and removing multiple work strings into the well is extremely time consuming and costly, it is even more time consuming and costly to complete boreholes with multiple producing zones within the same formation because each zone is typically completed and produced one at a time. It is highly desirable to complete all zones in a single trip. There is a need, therefore, for new systems and methods that allow the deployment of the entire completion hardware in a single trip for multiple zones. 
     SUMMARY 
     In a completion string deployed in a wellbore extending through a plurality of well zones, according to one or more embodiments of the present disclosure, the completion string includes: at least one isolation packer positioned between well zones of the plurality of well zones, the plurality of well zones including: a bottom-most well zone; and a top well zone; a washdown shoe disposed in the bottom-most well zone; a first sand control assembly and a first circulating assembly, each disposed uphole of the washdown shoe in the bottom-most well zone, wherein the top well zone includes a return valve assembly and a production packer, wherein the top well zone further includes a second sand control assembly; and a second circulating assembly, each of the second sand control assembly and the second circulating assembly being downhole of the production packer, wherein the completion string further includes an outer string spanning from the bottom-most well zone to the top well zone; and an inner production string concentrically arranged within the outer string creating an inner-annulus between the outer string and the inner production string, wherein the inner-annulus is continuous from the washdown shoe to the return valve assembly, the inner production string including a first production valve disposed between the first sand control assembly and the first circulating assembly in the bottom-most well zone; and a second production valve disposed between the second sand control assembly and the second circulating assembly in the top well zone. 
     In a completion string deployed in a wellbore extending through a plurality of well zones according to one or more embodiments of the present disclosure, the completion string includes at least one isolation packer positioned between well zones of the plurality of well zones, the plurality of well zones comprising: a bottom-most well zone; a top well zone; a washdown shoe disposed in the bottom-most well zone; a first sand control assembly and a first circulating assembly, each disposed uphole of the washdown shoe in the bottom-most well zone; an annular flow module and a production packer, each disposed in the top well zone, the top well zone further comprising a second sand control assembly and a second circulating assembly, each disposed downhole of the production packer, wherein the completion string further includes: an outer string spanning from the bottom-most well zone to the top well zone; and an inner production string concentrically arranged within the outer string creating an inner-annulus between the outer string and the inner production string, wherein the inner-annulus is continuous from the washdown shoe in the bottom-most well zone to the annular flow module in the top well zone, wherein the inner-annulus houses a shunt tube system, which facilitates directing flow between well zones of the plurality of well zones, and wherein annular flow above the production packer is directed to the shunt tube system via the annular flow module. 
     In a completion string deployed in a wellbore extending through a plurality of well zones according to one or more embodiments of the present disclosure, the completion string includes: at least one isolation packer positioned between well zones of the plurality of well zones, the plurality of well zones comprising: a bottom-most well zone; a top well zone; a washdown shoe disposed in the bottom-most well zone; a first sand control assembly disposed uphole of the washdown shoe in the bottom-most well zone, wherein the first sand control assembly cooperates with a first electric flow control valve and a shunt tube isolation valve, each disposed in the bottom-most well zone, wherein the top well zone includes: a circulating assembly; and a production packer adjacent to the circulating assembly, wherein the top well zone further includes a second sand control assembly that cooperates with a second electric flow control valve, and wherein each of the first and second sand control assemblies comprises at least one shunt tube. 
     However, many modifications are possible without materially departing from the teachings of this disclosure. Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       Certain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements. It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein, and: 
         FIG.  1    shows a completion string according to one or more embodiments of the present disclosure; 
         FIG.  2 A  shows further detail of the return valve of the completion string of  FIG.  1    according to one more embodiments of the present disclosure; 
         FIG.  2 B  shows further detail of the circulating assembly of the completion string of  FIG.  1    according to one or more embodiments of the present disclosure; 
         FIG.  2 C  shows further detail of a downhole flow control valve inside a sand control assembly of the completion string of  FIG.  1    according to one or more embodiments of the present disclosure; 
         FIG.  2 D  shows further detail of the downhole flow control valve inside the sand control assembly of  FIG.  2 C  according to one or more embodiments of the present disclosure; 
         FIGS.  3 A- 3 I  show a method of completing a wellbore in a single trip according to one or more embodiments of the present disclosure; 
         FIG.  3 J  shows a truth table of the system valves of the completion string in view of the method shown in  FIGS.  3 A- 3 I  according to one or more embodiments of the present disclosure; 
         FIG.  4    shows a completion string according to one or more embodiments of the present disclosure; 
         FIG.  5 A  shows further detail of the circulating assembly of the completion string of  FIG.  4    according to one or more embodiments of the present disclosure; 
         FIG.  5 B  shows further detail of a shunt tube return section of the completion string of  FIG.  4    according to one or more embodiments of the present disclosure; 
         FIG.  5 C  shows further detail of the shunt tube return section of  FIG.  5 B  according to one or more embodiments of the present disclosure; 
         FIGS.  6 A- 6 I  show a method of completing a wellbore in a single trip according to one or more embodiments of the present disclosure; 
         FIG.  6 J  shows a truth table of the system valves of the completion string in view of the method shown in  FIGS.  6 A- 6 I  according to one or more embodiments of the present disclosure; 
         FIG.  7    shows a completion string according to one or more embodiments of the present disclosure; 
         FIG.  8 A  shows further detail of the production packer of the completion string of  FIG.  7    according to one or more embodiments of the present disclosure; 
         FIG.  8 B  shows further detail of the circulating assembly of the completion string of  FIG.  7    according to one or more embodiments of the present disclosure; 
         FIGS.  8 C- 8 E  show different valve positions of the circulating assembly of  FIG.  8 B  according to one or more embodiments of the present disclosure; 
         FIGS.  9 A- 9 F  show a method of completing a wellbore in a single trip according to one or more embodiments of the present disclosure; and 
         FIG.  9 G  shows a truth table of the system valves of the completion in view of the method shown in  FIGS.  9 A- 9 F  according to one or more embodiments of the present disclosure. 
     
    
    
     DETAILED DESCRIPTION 
     In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure. However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible. 
     In the specification and appended claims: the terms “up” and “down,” “upper” and “lower,” “upwardly” and “downwardly,” “upstream” and “downstream,” “uphole” and “downhole,” “above” and “below,” and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments of the disclosure. 
     The present disclosure generally relates to a system and method for completing a wellbore. More specifically, the present disclosure relates to a completion string, such as a downhole circulation system, and a method for completing a wellbore requiring stimulation and/or sand control with or without downhole flow control in a single trip. 
     The completion design according to one or more embodiments of the present disclosure is a single trip gravel pack/frac pack completion string with integrated electrical flow control valves. Advantageously, monitoring of pressure, temperature, and other parameters is possible because the system according to one or more embodiments of the present disclosure allows electric and fiber optic lines to be run through the entire length of the completion string (including the sand face). In a method according to one or more embodiments of the present disclosure, the completion string or downhole circulation system is lowered in the wellbore and hung in the tubing hanger. All completion operations are performed from this position from setting packers until the well is put in production. As another advantage, because the completion design according to one or more embodiments of the present disclosure allows the wellbore to be completed in a single trip, completion installation and gravel packing/frac packing times are reduced, which translates into significant operational cost savings. 
       FIG.  1   - FIG.  3 J  relate to a completion design for a single trip gravel packing/frac packing completion string with integrated electrical flow control valves according to one or more embodiments of the present disclosure. Because the system allows electric and fiber optic lines to be run through the entire completion length, including the sandface, monitoring of pressure, temperature, and other parameters is possible. In one or more embodiments of the present disclosure, the completion string is lowered in a wellbore, hung in a tubing hanger, and all completion operations are performed from that position from setting packers, until the well is put in production. 
     The completion string according to one or more embodiments of the present disclosure does not require a service string to perform gravel packing or frac packing operations. Instead, the completion string according to one or more embodiments of the present disclosure is composed of two concentric strings, which coupled with several valves allow for certain required flow paths during the entire completion deployment. For example, fluid communication flow paths provided by the completion design of  FIG.  1   - FIG.  3 J  may include an outer annulus between the open hole and screens (i.e., where the gravel is pumped); a micro-annulus between screen wires and non-perforated base pipe (i.e., for the gravel pack fluid dehydration); an inner-annulus between the screen base pipe and inner production string (i.e., for taking return flow); tubing, or the inner diameter (ID) of the inner production string; and an upper-annulus above the production packer, between the casing and the tubing. In one or more embodiments of the present disclosure, the inner-annulus is connected from one zone to the next via a 4-way circulating assembly, which is further described below. 
     Referring specifically to  FIG.  1   , a completion string  10  according to one or more embodiments of the present disclosure is shown. In particular,  FIG.  1    shows a layout of the completion string  10  with its main components for a two zone completion. As shown in  FIG.  1   , the completion string  10  may include at least one isolation packer  12  or openhole packer between each well zone, separating two or more well zones. In one or more embodiments of the present disclosure, the at least one isolation packer  12  may include a melting isolating material, such as a metal or resin, for example. The well zones may include at least a bottom-most well zone in an uncased section of a wellbore and a top well zone in the uncased and cased sections of the wellbore. Of note, the completion string  10  according to one or more embodiments of the present disclosure may also operate in an entirely cased wellbore. Moreover, the well zones may also include any number of intermediate well zones between the bottom-most well zone and the top well zone according to one or more embodiments of the present disclosure. Each of the bottom-most well zone and any intermediate well zone includes from top to bottom an openhole or isolation packer  12 , a circulating assembly  14 , a sand control assembly  16  that includes a pair of screen joints coupled at a screen joint connection, a flow control valve  18  for taking returns, and an inner production string  20  having production valves  22 . Moreover, in one or more embodiments of the present disclosure, the bottom-most well zone may include a washdown shoe  24 , and the top well zone may include a return valve assembly  26  and a production packer  28  or control line set top packer that is hydraulically set in casing. In one or more embodiments of the present disclosure, the top well zone also includes a circulating assembly  14  and a sand control assembly  16  downhole of the production packer  28 . In one or more embodiments of the present disclosure, a sand control assembly  16  and a circulating assembly  14  are disposed uphole of the washdown shoe  24  in the bottom-most well zone. Further, a production valve  22  of the inner production string  20  is disposed between the sand control assembly  16  and the circulating assembly  14  in each of the bottom-most well zone and the top well zone, according to one or more embodiments of the present disclosure. 
     Still referring to  FIG.  1   , the production valve  22  according to one or more embodiments of the present disclosure is a one-off opening sleeve that is actuated via a rupture disc. In one or more embodiments of the present disclosure, the actuation command for the production valve  22  may be sent wirelessly via pressure signals, for example, once the well is to be put in production. That is, in one or more embodiments of the present disclosure, the production valve  22  may be remotely actuated via an electrical rupture disc. In other embodiments of the present disclosure, the production valve  22  may be actuated via a mechanical rupture disc. According to one or more embodiments of the present disclosure, the production valve  22  may include an inflow control device. Well suspension may be achieved, prior to opening the at least one production valve  22 , upon closing the return valve  26  and once the at least one production valve  22  is opened by closing the return valve  26  and at least the isolation valve  14   c  of the circulating assembly  14  in the top well zone. 
     As further shown in  FIG.  1   , the completion string  10  according to one or more embodiments of the present disclosure also includes an outer string  30  spanning from the bottom-most well zone to the top well zone. In one or more embodiments of the present disclosure, the inner production string  20  of the completion string  10  is concentrically arranged within the outer string  30  creating an inner-annulus  19  between the outer string  30  and the inner production string  20 . In one or more embodiments of the present disclosure, the separation of well fluids, for example oil from gas, may be achieved by continuing the concentric arrangement of the inner production string  20  within the outer string  30  all the way to surface. According to one or more embodiments of the present disclosure, the inner-annulus  19  is continuous from the washdown shoe  24  to the return valve assembly  26 .  FIG.  1    also shows that the completion string  10  according to one or more embodiments of the present disclosure may include an electric line  32  or a fiber optic line that runs through the entire length of the completion string  10 , including the sand face of the sand control assembly  16  in the bottom-most well zone. In this way, one or more embodiments of the present disclosure provide for an efficient single trip completion string that includes an upper and a lower completion without a need for a wet connection between the upper completion and the lower completion. 
     Referring now to  FIG.  2 A , further detail of the return valve  26  of the completion string  10  of  FIG.  1    according to one or more embodiments of the present disclosure is shown. The return valve  26  is a remotely operated sliding sleeve type of valve that allows communication between the upper-annulus and the inner-annulus of the production packer  28 , according to one or more embodiments of the present disclosure. In one or more embodiments, the return valve  26  may be actuated electrically or hydraulically. Referring to the truth table shown in  FIG.  3 J , the operational sequence for the return valve  26  requires three actuations in one or more embodiments of the present disclosure: the return valve  26  is in the closed position while the completion string  10  is run-in-hole, the return valve  26  is then opened for treatment and related steps, and the return valve  26  returns to the closed position before production. The return valve  26  may be remotely actuated via an electric rupture disc, according to one or more embodiments of the present disclosure. In such embodiments, the actuation command may be either sent wirelessly via pressure signals, or by using the electric line  32 . Alternatively, hydraulic actuations via an open line  34  and a close line is possible. 
     Referring now to  FIG.  2 B , further detail of the circulating assembly  14  of the completion string  10  of  FIG.  1    according to one or more embodiments of the present disclosure is shown. In one or more embodiments of the present disclosure, the circulating assembly  14 , one of the key components of the completion string  10 , is adjacent to each well zone. As shown in  FIG.  1   , in one or more embodiments of the present disclosure, there is one circulating assembly  14  per well zone downhole of the top well zone. In one or more embodiments of the present disclosure, the circulating assembly  14  is composed of 3 valves (e.g., a reverse valve  14   a , a treat valve  14   b , and an isolation valve  14   c ) that are controlled via a hydraulic-electric system. Upon reception of a command through the electric line  32 , the appropriate valve of the circulating assembly  14  is cycled through the control module  36 . 
     Still referring to  FIG.  2 B , the circulating assembly  14  according to one or more embodiments of the present disclosure allows for pumping fluid from the inner production string  20  to the outer annulus  25  (i.e., completion outer diameter to formation) via the treat valve  14   b , from the inner annulus to the inner production string  20  via the reverse valve  14   a , and inside the inner production string  20  or to isolate the completion string  10  below via the isolation valve  14   c . Advantageously, the 4-way connections of the circulating assembly  14  according to one or more embodiments of the present disclosure facilitate connection from one well zone to the next while preserving the inner annulus through the length of the completion string  10 . 
     Referring now to  FIG.  2 C , further detail of a flow control valve  18  inside the sand control assembly  16  of the completion string  10  of  FIG.  1    is shown according to one or more embodiments of the present disclosure. Specifically, the flow control valve  18  may be a Schlumberger Manara valve, and the sand control assembly  16  may be a Schlumberger MZ-Xpress screen, according to one or more embodiments of the present disclosure. Further, in one or more embodiments of the present disclosure, the sand control assembly  16  may be alternate path compatible for gravel packing applications. Moreover, the flow control valve  18  may be a full bore electric flow control valve, according to one or more embodiments of the present disclosure. 
     Referring to  FIGS.  1  and  2 C , in one or more embodiments of the present disclosure, the sand control assembly  16  includes a pair of screen joints coupled at a screen joint connection. Moreover, each screen joint of the sand control assembly  16  according to one or more embodiments of the present disclosure includes a non-perforated base pipe  17 , a filter medium  23  such as a screen disposed around the non-perforated base pipe  17 , and a micro-annulus  21  between the filter medium  23  and the non-perforated base pipe  17 . The sand control assembly  16  according to one or more embodiments of the present disclosure is unique at least because the micro-annulus  21  is continuous from screen joint to screen joint. In one or more embodiments of the present disclosure, the outer string  30  of the completion string  10  includes the non-perforated base pipe  17  of each screen joint and additional blank pipe  15 . Moreover, the sand control assembly  16  according to one or more embodiments of the present disclosure includes a feedthrough for the electric line  32  of the completion string  10 . 
     In embodiments of the present disclosure where there is at least one intermediate well zone between the bottom-most well zone and the top well zone, the completion string  10  may include an additional sand control assembly  16  and an additional circulating assembly  14  disposed in the at least one intermediate well zone. Moreover, in embodiments of the present disclosure having at least one intermediate well zone, the inner production string  20  may include an additional production valve  22  disposed between the sand control assembly  16  and the circulating assembly  14  in the at least one intermediate well zone. 
     Referring to  FIGS.  1 ,  2 C, and  2 D , which show further detail of the downhole flow control valve  18  in cooperation with the sand control assembly  16  of  FIG.  2 C  according to one or more embodiments of the present disclosure, the filter medium  23  of the sand control assembly  16  is offset from the base pipe  17  through high standoff rib wires, which allow for the placement of the flow control valve  18  (based off the Manara Valve tube). Integrating the sand control assembly  16  and the flow control valve  18  in each of the well zones in this way allows for optimized production. As shown in  FIG.  2 D , for example, the flow control valve  18  may include a plunger  18   a  and a venturi valve  18   b  in one or more embodiments of the present disclosure. As further shown in  FIG.  2 D , in an open configuration, the plunger  18   a  of the flow control valve  18  is offset from a port  17   a  in the base pipe  17  of the sand control assembly  16 , the port  17   a  allowing flow to the inner-annulus  19  between the base pipe  17  and the inner production string  20 .  FIG.  2 D  also shows that the plunger  18   a  of the flow control valve  18  shifts to obstruct the port  17   a  of the base pipe  17  so that no fluid may flow into the inner-annulus  19  in the closed configuration. 
     Still referring to  FIGS.  1  and  2 D , the system is modular as it allows one or multiple flow control valves  18  to be used in a given well zone. At a minimum, one flow control valve  18  cooperates with the sand control assembly  16  to allow for selective production and effective gravel pack placement in one or more embodiments of the present disclosure. In one or more embodiments of the present disclosure, the flow control valve  18  may be positioned inside the filter medium  23  (i.e., inside the micro-annulus  21  of the screen joint) as shown in  FIGS.  2 C- 2 D , or the flow control valve  18  may be positioned at a location next to the screen joint that is external to the micro-annulus  21  and the corresponding filter medium  23  (not shown). Moreover, the flow control valve  18  according to one or more embodiments of the present disclosure may be positioned above or below a screen joint of the sand control assembly  16 . An inflow control device may be positioned in the flow control valve  18  according to one or more embodiments of the present disclosure. 
     Referring now to  FIGS.  3 A- 3 I , a method of completing a wellbore in a single trip according to one or more embodiments of the present disclosure is shown. After making up all of the completion assemblies at the rotary, the completion string  10  may be deployed into the wellbore as shown in  FIG.  3 A  in a method according to one or more embodiments of the present disclosure. As further shown in  FIG.  3 A , in one or more embodiments of the present disclosure, fluid may be pumped through the inner production string  20 , down to and out of the washdown shoe  24  in bottom-most well zone, and into the outer annulus  25 . In preparation for subsequent treatment operations, the fluid cleans the outer annulus  25  as the fluid returns to the surface. Referring now to  FIG.  3 J , while the completion string  10  is run-in-hole and during washdown as shown in  FIG.  3 A , all system valves of the completion string  10  are closed except for the isolation valves  14   c  of the circulating assemblies  14 . Setting the system valves of the completion string  10  in this way facilitates pumping fluid from the tubing through the completion inner diameter (i.e., the inner production string  20 ) to the washdown shoe  24  and back to the completion annulus to surface. The open hole fluid can be displaced in that same position (i.e., tubing to annulus). To allow adequate fluid filling while running in hole, the return valve  26  and the reverse valves  14   a  of the circulating assemblies  14  may be cycled in the open position according to one or more embodiments of the present disclosure. 
     As shown in  FIG.  3 B , the method further includes setting the production packer  28  in one or more embodiments of the present disclosure. The production packer  28  is set via a hydraulic line  34  or electric line  32  according to one or more embodiments of the present disclosure. As shown in  FIG.  3 J , for example, when the production packer  28  is set, system valves of the completion string  10  are closed except for the isolation valves  14   c  of the circulating assemblies  14 . 
     Referring now to  FIG.  3 C , the method further includes pumping displacement fluid through the completion string  10  in an annulus-to-tubing direction. Advantageously, displacing the open hole in the annulus-to-tubing direction helps protect the screens  23  of the sand control assembly  16 . As shown in  FIG.  3 J , in this position, the return valve  26  is open, the top-most treat valve  14   b  of the top circulating assembly  14  is open, and the bottom-most flow control valve  18  is open. Also, in this position, the upper isolation valve  14   c  of the circulating assembly  14  is closed. In other embodiments of the present disclosure, displacement fluid may be pumped through the completion string  10  in a tubing-to-annulus direction. 
     Referring now to  FIG.  3 D , the method further includes setting the at least one isolation packer  12 . In one or more embodiments of the present disclosure, the at least one isolation packer  12  may be set hydraulically. For hydraulic setting of the at least one isolation packer  12 , pressure is conveyed to the setting section by pressuring the tubing annulus and opening the return valve  26 , all other system valves of the completion string  10  will remain closed except for the isolation valves  14   c  of the circulating assemblies  14 . In other embodiments of the present disclosure, the at least one isolation packer  12  may be set electrically, such as by an eFire or eTrigger that is actuated via the electric line  32 , for example. According to one or more embodiments of the present disclosure, the plurality of isolation packers  12  in the completion string may be set simultaneously. 
     Referring now to  FIG.  3 E , the method further includes treating the bottom-most well zone. In one or more embodiments of the present disclosure, treating the bottom-most well zone includes performing fracturing and gravel pack operations. In one or more embodiments, an annulus blowout preventer will be closed on the tubing, and treatment fluid is pumped down the inner production string  20 , out to the open hole through the treat valve  14   b  of the lower circulating assembly  14 , to the flow control valve  18  in the bottom-most well zone, up the inner string annulus  19 , and through the return valve  26  to surface. In one or more embodiments of the present disclosure, during this treating step, the lower isolation valve  14   c  of the circulating assembly  14  is closed, the lower treat valve  14   b  of the circulating assembly  14  is open, and the flow control valve  18  is open, as shown in  FIG.  3 J , for example. 
     Referring now to  FIG.  3 F , the method further includes reversing out the bottom-most well zone. In one or more embodiments of the present disclosure, this step enables reversing out the excess slurry that remains in the tubing following the gravel pack and fracturing treatments. As shown in  FIG.  3 J , during this reversing out step, the isolation valve  14   c  of the lower circulating assembly is closed, and the lower reverse valve  14   a  of the circulating assembly  14  is opened. In this position, fluid can be pumped from the tubing annulus through the return valve  26  and lower reverse valves  14   a  back to the inner production string  20  and then the tubing. The formation is isolated via the isolation valve  14   c  and treat valve  14   b  of the circulating assembly  14  and the bottom-most flow control valve  18 . 
     Referring now to  FIGS.  3 G and  3 H , the method further includes treating and reversing out the top well zone. In one or more embodiments of the present disclosure, the operation continues with steps identical to those shown in  FIGS.  3 E and  3 F  with the lower circulating assembly  14  fully closed and the lower flow control valve  18  fully closed, as shown in  FIG.  3 J , for example. That is, in the method according to one or more embodiments of the present disclosure, open hole or closed hole gravel packing/frac packing treatment operations and subsequent reverse out operations may be performed for a given zone, for each zone to be completed. 
     Referring now to  FIG.  31   , the method further includes putting the well in production by opening the production valves  22  in the completion string  10  to allow production fluid inside the inner production string  20  to be produced at surface. During this step of the method, as shown in  FIG.  3 J , the flow control valves  18  are opened, and the opening of the flow control valves  18  may be controlled to regulate the reservoir flow. As further shown in  FIG.  3 J , the production valves  22  are opened to allow fluid inside the inner production string  20 , and the isolation valves  14   c  of the circulating assemblies  14  are opened. 
       FIG.  4   - FIG.  6 J  relate to a completion design for a single trip gravel packing/frac packing completion string with integrated electrical flow control valves and a shunt tube system that facilitates directing flow between well zones of the plurality of well zones according to one or more embodiments of the present disclosure. Because the system allows electric and fiber optic lines to be run through the entire completion length, including the sandface, monitoring of pressure, temperature, and other parameters is possible. In one or more embodiments of the present disclosure, the completion string is lowered in a wellbore, hung in a tubing hanger, and all completion operations are performed from that position from setting packers, until the well is put in production. 
     The completion string  10  according to one or more embodiments of the present disclosure does not require a service string to perform gravel packing or frac packing operations. Instead, the completion string  10  according to one or more embodiments of the present disclosure includes an inner concentric string, i.e., the inner production string  20 , connected to the base pipe  17  of the sand control assembly  16 . Further, in the completion string  10  according to one or more embodiments of the present disclosure, the concentric annulus (or inner-annulus  19 ) flows are distributed with an internal shunt tube system  38  along the completion string  10 . For example, fluid communication flow paths provided by the completion design of  FIG.  4   - FIG.  6 J  may include an outer annulus between the open hole and screens (i.e., where the gravel is pumped); a micro-annulus between screen wires and non-perforated base pipe (i.e., for the gravel pack fluid dehydration); a shunt return tube placed adjacent to each well zone that allows fluid dehydration during gravel packing up to an annular flow module; an inner-annulus between the screen base pipe and inner production string, the inner-annulus housing a shunt tube manifold system that allows for directing flow from one zone to the next; tubing, or the ID of the inner production string, which is connected to the base pipe of the sand control assembly; and an upper-annulus above the production packer, between the casing and the tubing. In one or more embodiments of the present disclosure, the inner-annulus is connected from one zone to the next via a 4-way circulating assembly, which is further described below. Moreover, in one or more embodiments of the present disclosure, the inner-annulus is continuous from the washdown shoe  24  to the annular flow module  44  through the lower completion portion of the completion string  10 . 
     Referring to specifically to  FIG.  4   , a completion string  10  according to one or more embodiments of the present disclosure is shown. In particular,  FIG.  4    shows a layout of the completion string  10  with its main components for a two zone completion. As shown in  FIG.  4   , the completion string  10  may include at least one isolation packer  12  or open hole packer between a plurality of well zones, including a bottom-most well zone in the uncased section of the wellbore, a top well zone in the cased section of the wellbore, and at least one intermediate well zone in the uncased section of the wellbore between the bottom-most well zone and the top well zone. Of note, the completion string  10  according to one or more embodiments of the present disclosure may also operate in an entirely cased wellbore. In one or more embodiments of the present disclosure, the at least one isolation packer  12  may include a melting isolating material, such as a metal or resin, for example. Each of the bottom-most well zone and any intermediate well zone includes from top to bottom an openhole or isolation packer  12 , a circulating assembly  14 , blank pipe  15 , a sand control assembly  16  that includes a pair of screen joints coupled at a screen joint connection, a flow control valve  18  for taking returns, an inner production string  20  continuous with the base pipe  17 , and a shunt tube system  38  having a reverse tube  40  and a return tube  42 . Moreover, in one or more embodiments of the present disclosure, the bottom-most well zone may include a washdown shoe  24 , and the top well zone may include an annular flow module  44  and a production packer  28  or control line set top packer that is hydraulically set in casing. In one or more embodiments of the present disclosure, a sand control assembly  16  and a circulating assembly  14  are disposed uphole of the washdown shoe  24  in the bottom-most well zone. Further, a sand control assembly  16  and a circulating assembly  14  may be disposed downhole of the production packer  28  in the top well zone. 
     As further shown in  FIG.  4   , the completion string  10  according to one or more embodiments of the present disclosure also includes an outer string  30  spanning from the bottom-most well zone to the top well zone. In one or more embodiments of the present disclosure, the inner production string  20  of the completion string  10  is concentrically arranged within the outer string  30  creating an inner-annulus between the outer string  30  and the inner production string  20 . In one or more embodiments of the present disclosure, the separation of well fluids, for example oil from gas, may be achieved by continuing the concentric arrangement of the inner production string  10  within the outer string  30  all the way to surface. According to one or more embodiments of the present disclosure, the inner-annulus is continuous from the washdown shoe  24  in the bottom-most well zone to the annular flow module  44  in the top well zone. In one or more embodiments of the present disclosure, the inner-annulus houses a shunt tube system  38 , which facilitates directing flow between well zones. Moreover, annular flow above the production packer  28  is directed to the shunt tube system  38  via the annular flow module  44 . 
     According to one or more embodiments of the present disclosure, in the concentric annulus, the shunt tube system  38  splits annular flow according to the following principles. For example, the shunt tube system  38  includes a common annular tube  46  disposed in the top well zone of the inner-annulus of the completion string  10 . In one or more embodiments of the present disclosure, the common annular tube  46  splits for each well zone into a common return tube  42  and a common reverse tube  40 . In one or more embodiments, it is possible to include several common annular tubes  46  along the circumference. In other embodiments of the present disclosure, the shunt tube system  38  may include dedicated return and reverse tubes instead of a common annular tube that splits without departing from the scope of the present disclosure. As shown in  FIG.  4   , the common reverse tube  40  is connected to a reverse port  14   d  of each circulating assembly  14 , according to one or more embodiments of the present disclosure. As further described below, the reverse port  14   d  is opened via a ball or smart dart. A check valve in the reverse tube  40  allows only for downward flow. As also shown in  FIG.  4   , the common return tube  42  splits at a top of the bottom-most screen joint of a given well zone into a ported return tube  42   a , according to one or more embodiments of the present disclosure. A check valve inside each of the tubes of the split common return tube  42  allows only upward flow, according to one or more embodiments of the present disclosure. 
       FIG.  4    also shows that the completion string  10  according to one or more embodiments of the present disclosure may include an electric line  32  and/or a fiber optic line that runs through the completion string  10  at least from the top well zone to the circulating assembly  14  in the bottom-most well zone. In this way, one or more embodiments of the present disclosure provide for an efficient single trip completion string that includes an upper and a lower completion without a need for a wet connection between the upper completion and the lower completion. 
     Referring now to  FIG.  5 A , further detail of the circulating assembly  14  of the completion string  10  of  FIG.  4    according to one or more embodiments of the present disclosure is shown. In one or more embodiments of the present disclosure, the circulating assembly  14  of  FIG.  5 A  is a 4-way connecting system, such as that previously described. However, the circulating assembly  14  of  FIG.  5 A  is a three-position valve in one or more embodiments of the present disclosure. As shown in  FIG.  5 A , the circulating assembly  14  according to one or more embodiments of the present disclosure may include a treating port  14   e , a reverse port  14   d , and a degradable profile or seat  14   f  In a treat position of the circulating assembly  14 , the circulating assembly  14  is fully opened with the treating port  14   e  open and the reverse port  14   d  open. According to one or more embodiments of the present disclosure, the reverse port  14   d  and the treating port  14   e  are configured to open when the dart lands in the seat  14   f . Moreover, in the treat position, a check valve associated with the reverse port  14   d  facilitates isolation by only allowing for downward flow. In a reverse position of the circulating assembly  14 , the treating port  14   e  closes while the reverse port  14   d  remains open. In a closed position of the circulating assembly  14 , the circulating assembly  14  is fully closed with the treating port  14   e  and the reverse port  14   d  being isolated by a sleeve of the circulating assembly  14 . According to one or more embodiments of the present disclosure, the sleeve of the circulating assembly  14  is shifted by a dedicated ball or smart dart. Dedicated balls or darts would result in stage decreasing ID, as commonly used in multi-stage systems. In one or more embodiments of the present disclosure, the ball/dart and seat  14   f  of the circulating assembly  14  would degrade over time. In other embodiments of the present disclosure, the ball/dart would activate only in its dedicated profile without any ID reduction. In such embodiments, the seat profile  14   f  of the circulating assembly  14  may or may not be degradable; however, the ball/dart would need to be milled out post operation. In one or more embodiments of the present disclosure, the circulating assembly  14  is controlled via a hydraulic-electric system. 
     Referring now to  FIG.  5 B , further detail of a flow control valve  18  inside the sand control assembly  16  of the completion string  10  of  FIG.  4    is shown according to one or more embodiments of the present disclosure. Specifically, the flow control valve  18  may be a Schlumberger Manara valve, and the sand control assembly  16  may be a Schlumberger MZ-Xpress screen, according to one or more embodiments of the present disclosure. Further, in one or more embodiments of the present disclosure, the sand control assembly  16  may be alternate path compatible for gravel packing applications. Moreover, the flow control valve  18  may be a full bore electric flow control valve, according to one or more embodiments of the present disclosure. In one or more embodiments of the present disclosure, the flow control valve  18  may be positioned inside the filter medium  23  (i.e., inside the micro-annulus  21  of the screen joint) as shown in  FIGS.  5 B- 5 C , or the flow control valve  18  may be positioned at a location next to the screen joint that is external to the micro-annulus  21  and the corresponding filter medium  23  (not shown). Moreover, the flow control valve  18  according to one or more embodiments of the present disclosure may be positioned above or below a screen joint of the sand control assembly  16 . An inflow control device may be positioned in the flow control valve  18  according to one or more embodiments of the present disclosure. 
     Referring to  FIGS.  4  and  5 B , in one or more embodiments of the present disclosure, the sand control assembly  16  includes a pair of screen joints coupled at a screen joint connection. Moreover, each screen joint of the sand control assembly  16  according to one or more embodiments of the present disclosure includes a non-perforated base pipe  17 , a filter medium  23  such as a screen disposed around the non-perforated base pipe  17 , and a micro-annulus  21  between the filter medium  23  and the non-perforated base pipe  17 . The sand control assembly  16  according to one or more embodiments of the present disclosure is unique at least because the micro-annulus  21  is continuous from screen joint to screen joint. That is, the micro-annulus  21  according to one or more embodiments of the present disclosure is continuous through the given sand control assembly  16  of the given well zone. As further shown in  FIGS.  4  and  5 B , the flow control valve  18  as previously described may be positioned in the micro-annulus  21  of the bottom-most screen joint in one or more embodiments of the present disclosure. In other embodiments, the flow control valve  18  may be positioned outside the filter medium  23 , as previously described. Moreover, the flow control valve  18  may be positioned next to or within one of the screen joints according to one or more embodiments of the present disclosure. As further shown in  FIG.  4   , the inner production string  20  is continuous with the non-perforated base pipe  17  of the sand control assembly  16 . 
     Referring to  FIG.  5 B , further detail of the return section of the shunt tube system  38  of the completion string  10  of  FIG.  4    is shown according to one or more embodiments of the present disclosure. As shown in  FIG.  5 B , the return section of the shunt tube system  38 , which may include a return tube  42   a  and at least one return port  42   b , is disposed in the micro-annulus  21  between the filter/screen  23  and the non-perforated base pipe  17 . 
     Referring to  FIGS.  4 ,  5 B, and  5 C , which show further detail of the downhole flow control valve  18  in cooperation with the sand control assembly  16  according to one or more embodiments of the present disclosure, the filter medium  23  of the sand control assembly  16  is offset from the base pipe  17  through high standoff rib wires, which allow for the placement of the flow control valve  18  (based off the Schlumberger Manara valve tube). Integrating the sand control assembly  16  and the flow control valve  18  in each of the bottom-most and intermediate well zones in this way allows for optimized production. As shown in  FIG.  5 C , for example, the flow control valve  18  may include a plunger  18   a  and a venturi valve  18   b  in one or more embodiments of the present disclosure. As further shown in  FIG.  5 C , in an open configuration, the plunger  18   a  of the flow control valve  18  is offset from a port  17   a  in the base pipe  17  of the sand control assembly  16 , the port  17   a  allowing flow into the inner production string  20 .  FIG.  5 C  also shows that the plunger  18   a  of the flow control valve  18  shifts to obstruct the port  17   a  of the base pipe  17  so that no fluid may flow into the inner production string  20  in the closed configuration. 
     Referring back to  FIG.  4   , in one or more embodiments of the present disclosure, the at least one isolation (or open hole) packer  12  is set with hydraulic pressure when the annular flow module  44  is opened and applied inside the concentric annulus of the completion string  10 . The isolation packer  12  according to one or more embodiments of the present disclosure may be based off of an expandable steel annular zonal isolation packer, such as the Saltel AZIP, and may be rated up to 15 k psi, for example. According to one or more embodiments of the present disclosure, the isolation packer  12  includes a mandrel that is modified to allow bypass of the electric line  32 , shunts of the shunt tube system  38 , and annular flow, as shown in  FIG.  4   , for example. Setting ports of the isolation packer  12  are positioned in a plane offset from the concentric annulus of the completion string  10  and drilled radially in one or more embodiments of the present disclosure. In this way, the design of isolation packer  12  according to one or more embodiments of the present disclosure is similar to that of a regular crossover port body, or to the radial configuration of aforementioned circulation assemblies  14 . According to one or more embodiments of the present disclosure, an additional isolation packer  12  may be added between the washdown shoe  24  and the bottom-most screen joint to allow for a balanced fracturing operation. 
     Referring now to  FIGS.  6 A- 6 J , a method of completing a wellbore in a single trip according to one or more embodiments of the present disclosure is shown. After making up all of the completion assemblies at the rotary, the completion string  10  may be deployed into the wellbore as shown in  FIG.  6 A  in a method according to one or more embodiments of the present disclosure. As shown in  FIG.  6 J , while the completion string  10  is run-in-hole, all system valves of the completion string  10  are closed. As shown in  FIG.  6 A , while running in hole, the completion string  10  fills through the screens  23  of the sand control assembly  16  and ported shunts of the shunt tube system  38 . In one or more embodiments of the present disclosure, the annular flow module  44 , the flow control valves  18 , and the circulating assemblies are closed while the completion string  10  is run in hole. In one or more embodiments, this configuration allows fluid to be pumped from the tubing through the inner production string  20  to the washdown shoe  24  and back to the completion annulus to surface. 
     As shown in  FIG.  6 B , the method further includes pumping displacement fluid through the inner production string  20 , through the washdown shoe  24 , and back to surface via an outer annulus between the uncased section of the wellbore and the screens  23  of the sand control assemblies  16  in one or more embodiments of the present disclosure. This pumping displacement fluid step of the method according to one or more embodiments of the present disclosure may occur while the completion string is running in hole. As such, the system valves of the completion string  10  may assume the same configuration as previously described with respect to the run in hole step, as the displacement fluid flows in a tubing-to-annulus direction through the completion string  10 . 
     As shown in  FIG.  6 C , the method further includes setting the production packer  28  in one or more embodiments of the present disclosure. The production packer  28  is set via a hydraulic line  34  or electric line  32  according to one or more embodiments of the present disclosure. As shown in  FIG.  6 J , for example, when the production packer  28  is set, all system valves of the completion string  10  are closed. 
     As shown in  FIG.  6 D , the method further includes dropping a washdown shoe  24  deactivation mechanism  48  to set the at least one isolation packer  12  in one or more embodiments of the present disclosure. In one or more embodiments of the present disclosure, the deactivation mechanism  48  may be a ball, a dart, a plug, or any mechanism that is capable of obstructing the washdown shoe  24 . According to one or more embodiments of the present disclosure, all isolation packers  12  of the completion string  10  may be set simultaneously. In this step of the method according to one or more embodiments of the present disclosure, the at least one isolation packer  12  is hydraulically set, and pressure is conveyed to the setting section be pressuring the tubing against the deactivation mechanism  48  set in the washdown shoe  24  of the completion string. As shown in  FIG.  6 J , for example, when the at least one isolation packer  12  is set, all system valves of the completion string  10  are closed. 
     As further shown in  FIG.  6 E , the method further includes dropping a dart or ball  50  in the seat  14   f  of the circulating assembly  14  of the lower completion, and treating the bottom-most well zone. In one or more embodiments of the present disclosure, treating the bottom-most well zone includes performing fracturing and gravel pack operations. Dropping the dart or ball  50  in the seat  14   f  of the circulating assembly  14  of the lower completion opens the treating port  14   e  and the reverse port  14   d  of the circulating assembly  14 , as shown in  FIG.  6 J , for example. During this step of the method according to one or more embodiments of the present disclosure, the annular blowout preventer will be closed on the tubing, and treatment fluid is pumped down the inner production string  20  and out to the outer annulus of the completion string  10  through the treating port  14   e  of the lower circulating assembly  14 , through the screen jacket in between the screen jacket and the base pipe  17  to the return tube ports  42   b , up the return tube  42   a , up the inner string annulus, out the common annular tube  46 , and through the annular flow module  44  to the surface. Indeed, as shown in  FIG.  6 J , the annular valve of the annular flow module  44  is open during this treating step according to one or more embodiments of the present disclosure. 
     Referring now to  FIG.  6 F , the method further includes reversing out the bottom-most well zone according to one or more embodiments of the present disclosure. In one or more embodiments of the present disclosure, this step enables reversing out the excess slurry that remains in the tubing following the gravel pack and fracturing treatments. As shown in  FIG.  6 J , during this reversing out step, the treating port  14   e  of the circulating assembly  14  is closed via pressure pulse or electric signal. In this position, fluid can be pumped from the tubing annulus through the annular flow valve of the annular flow module  44  to the reverse tube  40  to the reverse port  14   d  back to the inner production string  20  and then the tubing. The formation is isolated via check valves of the shunt tube system  38  and the bottom-most flow control valve  18 . In one or more embodiments of the present disclosure, once the reverse operation is completed, another signal is sent, and the circulating assembly  14  is fully closed. 
     Referring now to  FIGS.  6 G and  6 H , the method further includes dropping an additional dart or ball  50  in the seat  14   f  of the circulating assembly  14  of the upper completion, treating the top well zone, and reversing out the top well zone. In one or more embodiments of the present disclosure, the operation continues with steps identical to those shown in  FIGS.  6 E and  6 F  with the lower circulating assembly  14  fully closed, as shown in  FIG.  6 J , for example. That is, in the method according to one or more embodiments of the present disclosure, open hole or closed hole gravel packing/frac packing treatment operations and subsequent reverse out operations may be performed for a given zone, for each zone to be completed. 
     Referring now to  FIG.  61   , the method further includes putting the well in production by opening the downhole flow control valve  18  of the sand control assembly  16 , and dissolving the darts/balls in the lower and upper completions to facilitate production through the inner production string  20  to be produced at surface. Opening the flow control valve  18  regulates the reservoir flow. During this step of the method, as shown in  FIG.  6 J , all other system valves are closed. 
       FIG.  7   - FIG.  9 G  relate to a completion design for a single trip open hole completion with electric flow control valves (eFCV) integrated with alternate path screens that allows multiple zones to be gravel packed simultaneously through shunts according to one or more embodiments of the present disclosure. The completion design according to one or more embodiments of the present disclosure does not require a service string. Upper and lower completions may be run together in a single trip in this completion design. The completion design according to one or more embodiments of the present disclosure provides full control of the production from each well zone. Because the system allows electric and fiber optic lines to be run through the entire completion length, including the sandface, monitoring of pressure, temperature, and other parameters is possible without needing a wetmate connection between the upper completion and the lower completion. The completion design according to one or more embodiments of the present disclosure may also be suitable for mechanical intervention. 
     As an example, fluid communication flow paths provided by the completion design of  FIG.  7   - FIG.  9 G  may include an outer annulus between the open hole and screens (i.e., where the gravel is pumped); a micro-annulus between screen wires and non-perforated base pipe (i.e., for the gravel pack fluid dehydration); shunts and nozzles associated with the alternate path screens; at least one shunt tube isolation valve; tubing, or ID of the inner production string; and an upper-annulus above the production packer between the casing and the tubing. In one or more embodiments of the present disclosure, the micro-annulus is continuous through the screen section of one given well zone. Moreover, in one or more embodiments of the present disclosure, the shunts associated with the alternate path screens are continuous from the bottom screen joint to the circulation assembly (i.e., through the “lower completion” of the completion string  10 ). That is, the shunts according to one or more embodiments of the present disclosure are connected from one well zone to the next via isolation or open hole packers and shunt tube isolation valves in the completion string  10 . 
     Referring specifically to  FIG.  7   , the completion string  10  according to one or more embodiments of the present disclosure is shown. In particular,  FIG.  7    a layout of the completion string  10  with its main components for a two zone completion. Although two well zones are shown in  FIG.  7   , more well zones may be easily added within the scope of the present disclosure. The number of well zones is limited by the friction losses in the shunts and the budget available for electrical power. Advantageously, the completion design shown in  FIG.  7    includes only a single string, which makes the completion design suitable to scale down to smaller open hole sizes. 
     As shown in  FIG.  7   , the completion string  10  may include at least one isolation packer  12  or open hole packer between a plurality of well zones, including a bottom-most well zone in the uncased section of the wellbore; and a top well zone in the uncased and cased sections of the wellbore. In one or more embodiments of the present disclosure, the isolation packer  12  between the bottom-most well zone and the at least one intermediate well zone may be replaced with an anchor, as shown in  FIG.  7   , for example. The bottom-most well zone and any intermediate well zone includes from top to bottom an openhole or isolation packer  12 , alternate path blank pipe  15 , a sand control assembly  16  with non-perforated base pipe  17 , and an electric flow control valve (eFCV)  13  cooperative with the sand control assembly  16  for taking returns. Moreover, in one or more embodiments of the present disclosure, the bottom-most well zone may include a washdown shoe  24 , and an eFCV  13  and a shunt tube isolation valve (STIV)  11  that cooperate with a sand control assembly  16  may each be disposed uphole of the washdown shoe  24  in the bottom-most well zone. In one or more embodiments of the present disclosure, the top well zone may include a circulating assembly  14  with a valve system and a production packer  28  or control line set top packer that is hydraulically set in casing. According to one or more embodiments of the present disclosure, the top well zone may also include an additional sand control assembly  16  that cooperates with an additional eFCV  13 , each of the additional sand control assembly  16  and the additional eFCV  13  being positioned downhole of the production packer  28  as shown in  FIG.  7   , for example. In one or more embodiments of the present disclosure, the circulating assembly  14  may be disposed in the uncased section of the wellbore. According to one or more embodiments of the present disclosure, the eFCV may be Schlumberger&#39;s Manara valve or a full bore electric flow control valve, and the STIV  11  may include an eTrigger for actuation of the valve, for example. 
     Still referring to  FIG.  7   , in one or more embodiments of the present disclosure, the sand control assembly  16  includes a pair of screen joints coupled at a screen joint connection. Moreover, each screen joint of the sand control assembly  16  according to one or more embodiments of the present disclosure includes a non-perforated base pipe  17 , a filter medium  23  such as a screen disposed around the non-perforated base pipe  17 , and a micro-annulus  21  between the filter medium  23  and the non-perforated base pipe  17 . The sand control assembly  16  according to one or more embodiments of the present disclosure is unique at least because the micro-annulus  21  is continuous from screen joint to screen joint. That is, the micro-annulus  21  according to one or more embodiments of the present disclosure is continuous through the given sand control assembly  16  of the given well zone. Moreover, the sand control assembly  16  according to one or more embodiments of the present disclosure includes a shunt tube  52 . In one or more embodiments of the present disclosure, the shunt tube  52  is continuous from the bottom screen joint of the sand control assembly  16  to the circulating assembly  14  (i.e., through the “lower completion” of the completion string  10 ). That is, the shunt tube  52  according to one or more embodiments of the present disclosure is connected from one well zone to the next via at least one isolation packer  12  and at least one STIV  11  in the completion string  10 . In one or more embodiments of the present disclosure, the filter medium  23  or screen of the sand control assembly  16  may be an alternate path screen such as Schlumberger&#39;s MZ-Xpress screen, for example. 
     Referring to  FIG.  8 A , further detail of the production packer  28  of the completion string  10  is shown. In one or more embodiments of the present disclosure, the production packer  28  is a multi-port production packer, such as Schlumberger&#39;s XMP packer, for example. In one or more embodiments, the multi-port production packer is tubing conveyed, hydraulically set, and retrievable via cut-to-release. The multi-port production packer according to one or more embodiments of the present disclosure may accommodate a plurality of bypass lines, and may have pressure and temperature ratings of 10,000 psi and 350° F., for example. In one or more embodiments of the present disclosure, the multi-port production packer may have sufficient radial space to accommodate up to six bypass lines. 
     Still referring to  FIG.  8 A , the multi-port production packer according to one or more embodiments of the present disclosure may include a bypass port for the return flow in the mandrel. In such embodiments, the multi-port production packer may include three bypass lines (i.e., one electrical line, one fiber optic line, and one circuit integrity line), and the radial space for the remaining three bypass lines may be repurposed and combined to achieve sufficient flow area. 
     Still referring to  FIG.  8 A , the multi-port production packer according to one or more embodiments of the present disclosure may be converted to a hydraulic set packer using Schlumberger&#39;s control line setting module. Such a configuration requires a control line in the upper completion (from the tubing hanger to the packer  28 ). Alternatively, an electric rupture disc may be used to set the packer  28 . In such embodiments, the actuation mechanism should include two atmospheric chambers. Triggering of the electric rupture disc can flood one of the atmospheric chambers with hydrostatic pressure and allow the piston to work against the other atmospheric chamber, setting the packer  28 . In one or more embodiments of the present disclosure, the triggering may be achieved either wirelessly using pressure signals or through a signal conveyed by the electric line  32 , such as that shown in  FIG.  7   , for example. 
     Referring now to  FIGS.  8 B- 8 C , further detail of the circulating assembly  14  of the completion string  10  according to one or more embodiments of the present disclosure is shown. As shown in  FIG.  8 B , the circulating assembly  14  includes an upper valve  14   g , a ball valve  14   h , and a lower valve  14   i . Further, as shown in  FIGS.  8 C- 8 E , the upper valve  14   g  of the circulating assembly  14  is configured to assume a closed position, a gravel packing position, and a reverse out position, according to one or more embodiments of the present disclosure. In other embodiments of the present disclosure, the circulating assembly  14  may include a single valve that is configured to function as the upper valve  14   g , the ball valve  14   h , and the lower valve  14   i , for example. As shown in  FIG.  7   , due to the shunt tube  52 , which is continuous from the bottom screen joint of the sand control assembly  16  to the circulating assembly  14 , the completion string  10  according to one or more embodiments of the present disclosure includes only one circulating assembly  14  for all well zones. 
     Referring now to  FIGS.  9 A- 9 G , a method of completing a wellbore in a single trip according to one or more embodiments of the present disclosure is shown. After making up all of the completion assemblies at the rotary, the completion string  10  may be deployed into the wellbore as shown in  FIG.  9 A  in a method according to one or more embodiments of the present disclosure. In one or more embodiments of the present disclosure, during run-in-hole, fluid may be pumped from the tubing through the completion ID to the washdown shoe  24  and back to surface through the completion annulus as shown in  FIG.  9 A , for example. As shown in  FIG.  9 G , while the completion string  10  is run-in-hole, the ball valve  14   h  of the circulating assembly  14  and the STIV  11  may be open, and all other system valves of the completion string  10  may be closed. In one or more embodiments of the present disclosure, the upper valve  14   g  of the circulating assembly  14  may also be open to facilitate adequate filling while running in hole. 
     As shown in  FIG.  9 B , the method further includes pumping displacement fluid through the completion string  10  in a tubing-to-annulus direction when the completion string  10  is in the run-in-hole configuration described above. Alternatively, to protect the screens  23 , the bottom-most eFCV  13  may be opened to displace the open hole in an annulus-to-tubing direction. 
     As shown in  FIG.  9 C , the method further includes setting the production packer  28  via a hydraulic or electric line  32 , according to one or more embodiments of the present disclosure. As shown in  FIG.  9 C , the method further includes setting the at least one isolation packer  12 . In one or more embodiments of the present disclosure, the at least one isolation packer  12  may be set electrically via an eTrigger. Further, in one or more embodiments of the present disclosure, all isolation packers  12  in the completion string  10  may be set simultaneously. 
     As shown in  FIG.  9 D , the method further includes gravel packing all well zones in the uncased section of the wellbore. Specifically, the completion string  10  according to one or more embodiments of the present disclosure allows gravel packing of multiple open hole well zones with full zonal isolation. According to one or more embodiments of the present disclosure, during gravel packing, the upper valve  14   g  of the circulating assembly  14  is in the gravel packing position shown in  FIG.  8 D . Also, during gravel packing, the ball valve  14   h  of the circulating assembly  14  is closed, the lower valve  14   i  of the circulating assembly  14  is open, all eFCV  13  are open, and the STIV  11  is open, as shown in  FIG.  9 G , for example. In this configuration, during graving packing, treatment fluid (i.e., gravel packing slurry) is pumped down the completion string  10  and out to the open hole through the lower valve  14   i  of the circulating assembly  14 . The slurry enters the shunt tubes  52  (i.e., alternate path transport tubes) and is transported to all the well zones (past the isolation packers  12  and the STIV  11 ). In each well zone, the slurry is diverted to packing tubes through manifolds. The slurry exits the packing tubes through a set of nozzles in each well zone and packs between the isolation packer  12  and the screens. The slurry is dehydrated through the screens  23  of the sand control assembly  16  and the eFCV  13  back to the tubing. That is, fluid enters into the micro-annulus  21  between the non-perforated base pipe  17  and screens  23  and is channeled to the eFCV  13  through the connected micro-annulus  21 . Thereafter, in one or more embodiments of the present disclosure, return fluid is diverted to the upper annulus above the production packer  28  through the lower valve  14   i  and the ball valve  14   h  of the circulating assembly  14 . 
     Referring now to  FIG.  9 E , the method further includes reversing out all gravel packed well zones. During reversing out, the upper valve  14   g  of the circulating assembly  14  is in the reverse out position, the ball valve  14   h  of the circulating assembly  14  is in the closed position, the lower valve  14   i  of the circulating assembly  14  is in the closed position, all eFCVs  13  are closed, and the STIV  11  is open. This configuration of the completion string  10  enables reversing out the excess slurry left in the tubing following the gravel packing procedure. Specifically, fluid may be pumped from the upper annulus to tubing displacing the excess slurry during the reversing out step according to one or more embodiments of the present disclosure. 
     Referring now to  FIGS.  9 F and  9 G , to prepare the completion string  10  for production, the upper valve  14   g  and the lower valve  14   i  of the circulating assembly  14  are set to closed, and the ball valve  14   h  of the circulating assembly  14  is set to the open position. Further, the STIV  11  is moved to the closed position to ensure total zonal isolation through the shunt tube. Moreover, the at least one eFCV  13  is set to the desired choking position, according to one or more embodiments of the present disclosure. In this configuration of the completion string  10 , production can start, as fluid is produced through the completion string  10 . 
     Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure. Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.