Patent Publication Number: US-9404333-B2

Title: Dual barrier open water well completion systems

Description:
BACKGROUND 
     This section provides background information to facilitate a better understanding of the various aspects of the disclosure. It should be understood that the statements in this section of this document are to be read in this light, and not as admissions of prior art. 
     In order to provide well control and maintain well integrity, it is desired to maintain two independently verified barriers in place at all times during the construction or suspension of the well. Well construction operations include all activities from the time the well is drilled until the well is completed and ready for production by installing a production control device, such as a Christmas tree. 
     Multiple wells may be drilled into a particular geological formation or hydrocarbon reservoir. The multiple wells may be drilled and completed in stages and therefore one or more of the wells may be suspend for a period of time. The suspended well can be re-entered at a later date and completed at a later date. 
     SUMMARY 
     A well completion system in accordance with one or more embodiments includes a shallow set barrier installed in an upper section of a well, a deep set barrier installed in a lower section of the well, a first sensor disposed to gauge a pressure in a first area between the deep set barrier and the shallow set barrier and a communication device to communicate the gauged pressure. The lower section may be located below a production completion when it is installed in the upper section. A method in accordance with an embodiment includes installing a deep set barrier valve in a lower section of a well, verifying integrity of the deep set barrier, installing a shallow set barrier in an upper completion section of the well, gauging the pressure in a first area between the shallow set barrier and the deep set barrier, suspending the well with the deep set barrier and the shallow set barrier in place, and gauging the pressure in the first area while the well is suspended. In accordance with some embodiments a well includes a subsea isolation device connected at the wellhead, an upper deep set barrier and a lower completion providing a lower deep set barrier, a gravel pack port formed through the lower completion, a device sealing the gravel pack port and sensors gauging pressure between the barriers. 
     The foregoing has outlined some of the features and technical advantages in order that the detailed description of the dual barrier open water completion system that follows may be better understood. Additional features and advantages of the dual barrier open water completion system will be described hereinafter which form the subject of the claims of the invention. This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of claimed subject matter. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       Embodiments of dual barrier open water completion system are described with reference to the following figures. The same numbers are used throughout the figures to reference like features and components. It is emphasized that, in accordance with standard practice in the industry, various features are not necessarily drawn to scale. In fact, the dimensions of various features may be arbitrarily increased or reduced for clarity of discussion. 
         FIGS. 1-21  illustrate a dual barrier well completion system in accordance to one or more embodiments having a lower barrier that may be opened when running an intermediate completion and an upper completion. 
         FIGS. 23-42  illustrate a dual barrier well completion system in accordance to one or more embodiments having a lower barrier that may be closed while running an intermediate and opened when setting the production completion. 
         FIGS. 43-55  illustrate a dual barrier well completion system in accordance to one or more embodiments having a lower barrier that is monitored and the lower barrier may remain closed until after a Christmas tree is installed. 
         FIGS. 56-68  illustrate a dual barrier well completion system in accordance to one or more embodiments having two lower barriers that are opened after installation of a Christmas tree and monitoring between the barriers. 
         FIGS. 69-89  illustrate a dual barrier well completion system in accordance to one or more embodiments having a monitoring system installed behind the casing and monitoring between the barriers. 
         FIGS. 90-103  illustrate a dual barrier well completion system in accordance to one or more embodiments including a lower completion with two packers and two barrier valves and monitoring between the barriers. 
         FIGS. 104-117  illustrate a dual barrier well completion system in accordance to one or more embodiments including a lower completion with two packers and two barrier valves, a behind the casing monitoring system and monitoring between the barriers. 
         FIGS. 118-120  illustrate a dual barrier well completion system in accordance to one or more embodiments including wireless communication of data gauged between the barriers and a lower completion with two packers and two barrier valves. 
     
    
    
     DETAILED DESCRIPTION 
     It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments. Specific examples of components and arrangements are described below to simplify the disclosure. These are, of course, merely examples and are not intended to be limiting. In addition, the disclosure may repeat reference numerals and/or letters in the various examples. 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. 
     In the specification and appended claims: the terms “connect,” “connection,” “connected,” “in connection with,” and “connecting” are used to mean “in direct connection with” or “in connection with via one or more elements”; and the term “set” is used to mean “one element” or “more than one element”. Further, the terms “couple,” “coupling,” “coupled,” “coupled together,” and “coupled with” are used to mean “directly coupled together” or “coupled together via one or more elements”. As used herein, the terms “up” and “down,” “upper” and “lower,” “upwardly” and downwardly,” “upstream” and “downstream,” “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. As used herein: the abbreviation “FIV” is understood to mean “formation isolation valve”; the abbreviation “POOH” is understood to mean “pulled out of the hole”; the abbreviation “RIH” is understood to mean “run in hole”; the abbreviation “GP” is understood to mean “gravel pack”; the abbreviation “SCSSV” is understood to mean “surface controlled subsurface safety valve”; the abbreviation “PCS” is understood to mean “port closure sleeve”; and “ICD” is understood to mean “inflow/outflow control device”. 
     In some subsea wells a blow-out-preventer (BOP) and riser system are used at the well surface to maintain pressure and keep the hydrocarbon from the surrounding seawater. However, installation of the BOP and riser system is costly in that sea based surface equipment, such as platforms, are typically deployed in order to install the components. If these components are not deployed, then the well integrity relies largely on the completion barrier valves that are deployed as part of the completion system. In these cases, monitoring of the completion system downhole of the barrier valves can provide information as to the functionality of the barrier valves. In some embodiments, a completion system installed in an “open water” well may have two or three barrier valves, as well as a subsea isolation device installed at the wellhead. Subsea isolation devices may differ from blow out preventers in size and function, and may be installed from a non-platform surface asset such as a ship. 
     In some embodiments of an open water completion system, a lower barrier may not be monitored, and the lower barrier is open while running the intermediate completion section. A lower sand control completion may be run-in-hole, the lower completion including at least a gravel packing packer, a gravel packing port and a FIV type barrier valve. Next an intermediate completion may be run-in-hole, the intermediate completion including a dual trip saver type FIV, an intermediate packer, an open/close shifting tool, an open only shifting tool, and a straddle seal assembly. The intermediate completion mates with the lower completion, the open only shifting tool opening the lower completion barrier valve, and the straddle seal sealing the gravel packing port. The intermediate packer is set (e.g. with a drop ball), and the deployment tool is pulled out of hole, leaving the lower barrier valve open, and closing the upper or deep set barrier valve (i.e., dual trip saver FIV). At this point, the deep set barrier valve is the only separation between the well and the open water. 
     A shallow set plug assembly may be installed at a location uphole from the deep set barrier valve, for instance, at a location closer to the wellhead. The shallow set barrier assembly may include: a pressure sensor or gauge, suitable to measure pressure in the area between the deep set barrier valve and the shallow set barrier; a communication means (e.g. an inductive coupler or an electrical wet connect, or wireless transmitter) and a barrier (plug or FIV). Once the shallow set barrier is in place, the well is separated from the open water by the deep set barrier and the shallow set barrier. The pressure between the two barriers may be measured or gauged by the pressure gauge. Any fluctuation in pressure over time could be indicative of a leak in the deep set barrier valve. Once the shallow set barrier is in place, the well may be suspended for a period of time (e.g. 6 months, 1 year) until further completion components (e.g. Christmas tree assembly) are installed. During this suspension time pressure may be monitored in several ways. When the communication means comprises an inductive coupler assembly (e.g. a female coupler coupled to the pressure gauge), a male inductive coupler portion may be periodically lowered and engaged with the female inductive coupler portion to provide energy and communication with the pressure gauge. A pressure reading may then be taken and compared to the initial pressure reading. Likewise, an electrical wet connect would allow for the periodic engagement from surface (e.g. a ship) of a tool deployed by coiled tubing, wireline, etc., which engages with the shallow set barrier valve communication means to determine pressure information. In some embodiments, the communication means might include an acoustic or wireless data transmission module that is battery powered and installed. The wireless data transmission may communicate periodically with a surface asset, such as a ship or a surface receiver. As suspension periods of wells are commonly about 1 year in length, battery life for the wireless transmitter should not be a limiting factor. The initial suspension period would be the time between the installation of the lower and upper completion segments. While pressure gauges were discussed herein, one of skill in the art will recognize that other gauges (flow, temperature, etc.) may also be deployed. 
     When the upper completion is to be installed, the pressure readings between the shallow set and deep set barriers would be examined for evidence of leaks or other problems. Barring that, the shallow set barrier may be removed and the upper completion run-in-hole and installed. Various embodiments, as disclosed herein, are possible wherein a completion system includes barrier valves and maintains well pressure without the use of a blowout preventer. 
     Referring to  FIGS. 1-22  an open water completion system is described in which dual barrier monitoring systems and methods in accordance to one or more embodiments are implemented. In accordance with an embodiment, a lower barrier  36  of a lower completion  26  may be open while running an intermediate completion  38  and the production completion  86 . The lower barrier may or may not be monitored.  FIG. 1  illustrates an open water completion system, generally denoted by the numeral  5 , having a subsea well or wellbore  10  drilled from a seabed  12  to an earthen formation  9 . A blowout preventer (BOP) stack  14  has been landed on a wellhead  16  in the depicted well. BOP stack  14  commonly includes one or more sets of each of pipe rams to close on pipe, blind rams to close over an open wellbore, and shear rams to cut the pipe passing through the BOP stack. A marine riser  18  extends from BOP stack  14  to a surface rig  20  located at water surface  22 . Surface rig  20  is illustrated in  FIG. 1  as a platform and marine riser  18  may extend for example one-thousand feet or more through water  7 . In accordance with some embodiments, BOP stack  14  may be located at the top of marine riser  18  and a subsea isolation device may be installed at wellhead  16 . Casing  24 , i.e., a casing string, extends downward from wellhead  16  toward the formation. The A-annulus will be formed in casing  24  when the production tubing is installed. 
       FIG. 1  illustrates a lower completion  26  that has been run into the hole (RIH) and landed in a lower section  28  of casing  24  distal from wellhead  16 . The lower section  28  of the casing may be located below the lower most end of the upper, or production completion when it is installed. Lower completion  26  is illustrated as a sand control completion including a gravel packing packer  30 , tubular  32  (i.e., casing, liner), gravel pack port  34 , and a formation isolation valve (FIV) type of barrier valve  36 . Gravel pack may be circulated down well  10  and through gravel pack port  34 . 
     In  FIG. 2  an intermediate completion  38  is RIH on a deployment tool  40 . In this example, intermediate completion  38  includes an intermediate packer  42 , a formation isolation valve (FIV) type barrier valve  44  ( FIG. 5 ), and a straddle seal assembly  46 . FIV barrier valve  44  may be a dual trip saver valve wherein the valve may be opened two times in response to applied pressure in the well without requiring a shifting tool to open the valve. The illustrated deployment tool  40 , for example tubing, includes an open-close shifting tool  48  and an open only shifting tool  50 . 
     Referring in particular to  FIGS. 2 to 5 , intermediate completion  38  is illustrated mated with lower completion  26  with straddle seal assembly  46  sealing gravel packing port  34  and open only shifting tool  50  opening ( FIG. 3 ) lower completion FIV barrier valve  36 . A ball  52  is dropped ( FIG. 4 ) and intermediate packer  42  is set to engage casing  24 . Deployment tool  40  is illustrated in  FIG. 5  being pulled out of the hole (POOH) and intermediate FIV barrier valve  44  closed by open-close shifting tool  48 . 
       FIG. 6  illustrates lower barrier valve  36  open and intermediate barrier valve  44  closed. Intermediate packer  42  and closed intermediate valve  44  provide a deep set barrier  54 . Deep set barrier  54  may be pressure tested, illustrated by the arrow  3 , to ensure seal integrity. At this stage, deep set barrier  54  is the only separation in well  10  between formation  9  and the open water if the seabed isolation device, BOP stack  14  in this example, is removed. 
       FIG. 7  illustrates a shallow set barrier  56  landed in casing  24 . Shallow set barrier  56  is landed at a location uphole from deep set barrier  54  closer to wellhead  16 . For example, shallow set barrier  56  is set in a section  58  of well  10  in which the production completion may be landed. In  FIGS. 7-9 and 12 , shallow set barrier  56  includes a packer  55  and plug  57 . Shallow set barrier  56  may be formed by other devices, such as and without limitation a valve such as a mechanical formation isolation type valve. With reference to  FIGS. 10 and 11 , shallow set barrier  56  is illustrated as a mechanical type of formation isolation valve  59  coupled with a packer  55 . 
     The open water completion system  5  includes a monitoring system  60  to at least measure and monitor pressure in the area  62  between the shallow set barrier  56  and deep set barrier  54 . Monitoring system  60  includes a sensor  64  coupled with a communication device  66 , for example and without limitation an induction coupler or wet connect. Sensor  64  measures or gauges at least pressure and may gauge characteristics in addition to pressure, for example temperature and flow rate. In this example, monitoring system  60  is incorporated in shallow set barrier  56  with sensor  64  in communication with the area  62  between the deep set barrier  54  and the shallow set barrier  56 . 
     In  FIG. 7  a communication coupler  68  is illustrated RIH from water surface  22  on a deployment  70  and operationally coupled with communication device  66  thereby connecting sensor  64  with surface controls, for example rig  20 . Deployment  70  may be, for example, wireline, digital slick line, or tubing. Any fluctuation in pressure over time could be indicative of a leak in deep set barrier  54 . In accordance to embodiments, deep set barrier  54  and shallow set barrier  56  are independently testable, for example by pressure testing, and independently monitored. 
     Once the two barriers  54 ,  56  are set, well  10  may be suspended for a period of time, for example six months or more, until additional completion components (e.g. Christmas tree) are installed.  FIG. 8  illustrates dual barriers  54 ,  56  in place and well  10  suspended. BOP stack  14  and marine riser  18  illustrated in  FIG. 7  may be disconnected from well  10 . A subsea or seabed isolation device (SID)  72 , as shown in  FIG. 8 , may be connected to wellhead  16  in place of a BOP stack. A subsea isolation device may be similar to a subsea BOP stack but lacking for example the shear rams or another type of isolation device such as lower riser package. As will be understood by those skilled in the art with benefit of this disclosure, a subsea isolation device may not be utilized while the well is suspended. 
       FIGS. 9 to 13  illustrate examples of continuous and periodic monitoring of dual barrier open completions  5  while the well is suspended. Non-limiting examples of wired communication and monitoring is depicted in  FIGS. 9 and 10 .  FIG. 9  illustrates a communication coupler  68  deployed for example from a surface vessel (e.g. ship)  74  on a deployment  70  (e.g. tubing, wireline, digital slick line). Communication coupler  68  is shown in  FIG. 9  deployed through a riser  76  which may be an intervention or open water type of riser as opposed to a marine riser as utilized during drilling operations. Communication coupler  68  is illustrated in  FIG. 10  deployed through open water  7  and coupling monitoring system  60  with a surface receiver, for example vessel  74 . As will be understood by those skilled in the art with benefit of this disclosure, control and communication systems (electronics, hydraulics) may be provided at the seabed, for example via station  108  illustrated in  FIG. 20 . 
     Non-limiting examples of wireless monitoring of dual barrier open water completions  5  are illustrated in  FIGS. 11 and 12 . Communication coupler  68  is depicted in  FIG. 11  as a wireless data communication module which may include a battery and wireless acoustic data transmission electronics. In  FIG. 12 , monitoring system  60  includes an acoustic communication module  78  operationally coupled with sensor  64  to transmit data, for example acoustically, to surface vessel  74 . Communication module  78  may include for example an electrical source (e.g. battery), and electronics for transmitting and receiving data. 
       FIG. 13  illustrates an example of monitoring pressure in area  62  between deep set barrier  54  and shallow set barrier  56  and monitoring the pressure below deep set barrier  54 . Intermediate completion  38  includes a sensor  80  operationally connected to a communication device  82 . Sensor  80  is in communication with the pressure below packer  42  and barrier valve  44 , for example via a port  84 , to sense the pressure below deep set barrier  54 . Sensor  80  may gauge characteristics or parameters, for example temperature and flow rate, in addition to gauging pressure. Lower barrier valve  36  is open in  FIG. 13  providing communication with the area  134 . When barrier valve  36  is closed, sensor  80  monitors the area  118  (e.g.  FIG. 118 ) between the closed barrier valves  44 ,  36 . Again, pressure sensor  80  may sense or measure characteristics in addition to pressure, for example temperature and flow rate. Communication device  82  may transmit data from pressure sensor  80  to monitoring system  60 . For example, communication device  82  may transmit through acoustic wireless data transfer or by tube wave in casing fluid column to shallow set communication device  78  which receives and may transmit the data to a surface receiver, for example vessel  74  or a seabed station  108  ( FIG. 20 ). In accordance to some embodiments, communication device  82  may be for example an induction coupler or electrical wet connect for wired communication to a shallow set receiver and or a surface receiver. 
     Referring now to  FIGS. 14 to 22 , a method of completing the well with a production completion without having the need to install a BOP stack after the well was suspended is described. Referring back to  FIGS. 7-13 , shallow set barrier  56  is shown located in the upper section  58  of the well in which a production completion will be installed. To complete the well with the production completion, shallow set barrier  56  ( FIG. 13 ) is retrieved from the well as shown in  FIG. 14 . A surface isolation device  72  is shown installed at wellhead  16  with only one subsurface barrier, deep set barrier  54 , in place. Deep set barrier  54  may be pressured tested as illustrated by the arrow  3  in  FIG. 14 . 
     An upper completion  86 , also referred to as a production completion, is RIH and landed as illustrated for example in  FIG. 15  providing a deep set barrier  54  and a shallow set barrier  56 . Upper completion  86  can be RIH through SID  72 , for example, through open water  7 , or through an open water or intervention type riser. Upper completion  86  includes, for example, tubing  88  suspended from a tubing hanger  90  landed at wellhead  16 , and a barrier valve  92  and a production packer  94 . Shallow set barrier  56  is formed by barrier valve  92  and production packer  94  and is located in the upper section  58  of the well and can be tested independent of deep set barrier  54 . Barrier valve  92  is illustrated in  FIG. 15  as a surface controlled formation isolation valve (SFIV). Production packer  94  may be located at a lower end of tubing  88  and landed above the intermediate completion and deep set barrier  54 . Upper completion  86  includes a surface controlled subsurface safety valve (SCSSV)  96  located proximate barrier valve  92  in  FIG. 15 . Monitoring system  60  may be incorporated with upper completion  86 . For example, sensor  64  may be integrated with tubing  88  to monitor pressure in the area  62 , e.g. tubing bore, between deep set barrier  54  and shallow set barrier  56 . Sensor  64  may sense pressure in tubing  88  bore and or the tubing-casing annulus. Sensor  64  may be connected to the surface receiver via communication device  66  illustrated as a cable in  FIG. 15 . Barrier valve  92  and shallow set barrier  56  can be pressure tested as illustrated by the arrow  3  in  FIG. 15 , providing an integrity test independent of the testing of deep set barrier  54 . 
     Barrier valve  92  may be operated to an open position via a control line  98  from a controller (e.g. electronic, hydraulic), generally represented by vessel  74  and station  108  in  FIG. 20 . As will be understood by those skilled in the art with benefit of this disclosure, the surface controller (e.g. vessel  74 ) may be located at water surface  22 , the seabed or at a remote operated vehicle (ROV). Control line  98  may extend to water surface  22  for example along a marine riser  18  ( FIG. 1 ) or an open-water or intervention riser  76  ( FIG. 7 ). Similarly, subsurface safety valve  96  includes a control line  99 . 
     After verifying the integrity of shallow set barrier  56 , a suspension plug  100  shown in  FIG. 16  is landed in tubing hanger  90  forming an additional barrier  102 . Subsea isolation device  72  may then be retrieved suspending the well as illustrated in  FIG. 17 .  FIG. 17  illustrates the well with three barriers, deep set barrier  54 , shallow set barrier  56  and additional shallow set barrier  102  and without a BOP stack or subsurface isolation device connected with wellhead  16 . 
       FIG. 18  illustrates a Christmas tree  104  (i.e., production tree, valve tree) landed and connected to wellhead  16 . Tree  104  may be landed through open water  7  for example with assistance of a remote operated vehicle (ROV)  106 . After tree  104  has been installed, suspension plug  100  is retrieved as shown in  FIG. 19 . In  FIG. 20 , barrier valve  92  is opened via pressure applied via control line  98  for example from a station  108  located at seabed  12 . Tubing  88  pressure is applied in  FIG. 21  opening barrier valve  44 . As previously described, barrier valve  44  may be a dual trip saver FIV valve and a second tubing pressure signal may be applied if the first tubing pressure signal does not open barrier valve  44 .  FIG. 22  illustrates well  10  on production and producing fluid  110  from formation  9 . 
     Referring now to  FIGS. 23-42 , an open water completion system is described in which dual barrier monitoring systems and methods in accordance to one or more embodiments are implemented. In accordance with an embodiment, a lower barrier valve  36  may be closed while running an intermediate completion  38  and while running the production completion  86 . The lower barrier valve may be opened when setting the production completion. 
       FIG. 23  illustrates an open water completion system, generally denoted by the numeral  5 , having a subsea well or wellbore  10  drilled from a seabed  12  to an earthen formation  9 . A blowout preventer (BOP) stack  14  has been landed on a wellhead  16  in the depicted well. BOP stack  14  commonly includes one or more sets of each of pipe rams to close on pipe, blind rams to close over an open wellbore, and shear rams to cut the pipe passing through the BOP stack. A marine riser  18  extends from BOP stack  14  to a surface rig  20  located at water surface  22 . Surface rig  20  is illustrated in  FIG. 23  as a platform and marine riser  18  may extend for example one-thousand feet or more through water  7 . In accordance with some embodiments, BOP stack  14  may be located at the top of marine riser  18  and a subsea isolation device may be installed at wellhead  16 . The A-annulus will be formed in casing  24  when the production tubing is installed. 
       FIG. 23  illustrates a lower completion  26  that has been run into the hole (RIH) and landed in a lower section  28  of casing  24  distal from wellhead  16 . Lower completion  26  is illustrated as a sand control completion including a gravel packing packer  30 , tubular  32  (i.e., casing, liner), gravel pack port  34 , and a formation isolation valve (FIV) type of barrier valve  36 . 
     In  FIG. 24  an intermediate completion  38  is RIH on a deployment tool  40 . In this example, intermediate completion  38  includes an intermediate packer  42 , a formation isolation valve (FIV) type barrier valve  44  ( FIG. 27 ), and a straddle seal assembly  46 . FIV barrier valve  44  may be a dual trip saver valve wherein the valve may be opened two times in response to applied pressure in the well without requiring a shifting tool to open the valve. The illustrated deployment tool  40 , for example tubing, includes an open-close shifting tool  48 . Deployment tool  40  may not include an open-only shifting tool as depicted for example in  FIG. 2 . 
     Referring in particular to  FIGS. 24 to 27 , intermediate completion  38  is RIH and mated with lower completion  26  with straddle seal assembly  46  sealing gravel packing port  34 . Lower barrier valve  36  remains closed. A ball  52  is dropped ( FIG. 26 ) and intermediate packer  42  is set to engage casing  24 . Deployment tool  40  is illustrated in  FIG. 27  being pulled out of the hole (POOH) and intermediate FIV barrier valve  44  closed by open-close shifting tool  48 . Two barriers are closed and in place in  FIG. 27 . With port  34  sealed, packer  30  and barrier valve  36  form a lower deep set barrier  112  and barrier valve  44  and intermediate packer  42  form a second, upper, deep set barrier  114 .  FIG. 28  illustrates deep set barrier  114 , e.g. barrier valve  44 , being pressure tested, illustrated by the arrow  3 , to ensure seal integrity. The integrity of lower barrier valve  36  can be verified, for example by pressure testing, prior to closing barrier valve  44 . 
       FIG. 29  illustrates a shallow set barrier  56  landed in casing  24 . For example, shallow set barrier  56  is set in the section  58  of the well in which the production completion may later be installed. Shallow set barrier  56  is illustrated including a packer  55  and plug  57 . Shallow set barrier  56  may be formed by other devices, such as and without limitation a valve such as a mechanical formation isolation type valve. 
     The open water completion system  5  includes a monitoring system  60  to at least measure, i.e., gauge, and monitor pressure in area  62  between shallow set barrier  56  and the deep set barriers. Monitoring system  60  includes a sensor  64  coupled with a communication device  66 , for example and without limitation an induction coupler or wet connect. Sensor  64  measures at least pressure and may gauge characteristics in addition to pressure, for example temperature and flow rate. In this example, monitoring system  60  is incorporated in shallow set barrier  56  with sensor  64  in communication with the area  62  between barrier  114  and the shallow set barrier  56 . 
     In  FIG. 29  a communication coupler  68  is illustrated RIH from water surface  22  on a deployment  70  and operationally coupled with communication device  66  thereby connecting sensor  64  with surface controls, for example rig  20 . Deployment  70  may be, for example, wireline or tubing. Any fluctuation in pressure over time could be indicative of a leak in the barriers. In accordance to embodiments the barriers are independently testable, for example by pressure testing, and independently monitored. 
     Once two independently verifiable barriers are in place the well may be suspended for a period of time, for example six months or more, until additional completion components (e.g. Christmas tree) are installed.  FIG. 30  illustrates three barriers  112 ,  114  and shallow set barrier  56  in place. BOP stack  14  and marine riser  18  illustrated in  FIG. 29  may be disconnected and removed from wellhead  16 . A subsea or seabed isolation device (SID)  72 , as shown in  FIG. 30 , may be connected to wellhead  16  in place of a BOP stack. A subsea isolation device may be similar to a subsea BOP stack but lacking for example the shear rams or another type of isolation device such s lower riser package. As will be understood by those skilled in the art with benefit of this disclosure, the subsea isolation device and BOP stack may be removed while the well is suspended in accordance with embodiments disclosed herein. 
     After the well has been suspended for a period of time the pressure in area  62  is checked to determine if there is a leak and verify the integrity of the barriers. For example, in  FIG. 31  a surface vessel  74  is moved on site and a communication coupler  68  is deployed on a deployment  70  (e.g. tubing, wireline) into the well and connected with monitoring system  60 . Communication coupler  68  is shown in  FIG. 31  deployed through a riser  76  which may be an intervention or open water type of riser as opposed to a marine riser as utilized during drilling operations. At least the pressure in area  62  between shallow set barrier  56  and barrier  114  is checked to determine if there is a leak. Shallow set barrier  56  is retrieved after checking and confirming the integrity of the deep set barrier  114 . Deep set barrier  114 , i.e. barrier valve  44 , is pressure tested as illustrated by the arrows  3  in  FIG. 32 . 
     An upper completion  86 , also referred to as a production completion, is RIH and landed as illustrated for example in  FIG. 33  providing two deep set barriers  112 ,  114  and a shallow set barrier  56 . Upper completion  86  can be RIH through SID  72 , for example through an open water or intervention type riser  76  or through open water  7 . Upper completion  86  includes, for example, tubing  88  suspended from a tubing hanger  90  landed at wellhead  16 , a barrier valve  92  and a production packer  94 . Shallow set barrier  56  is formed by barrier valve  92  and production packer  94  and/or tubing hanger  90  and is located in the upper section  58  of the well and can be tested independent of the deep set barriers. Barrier valve  92  is illustrated in  FIG. 33  as a surface controlled formation isolation valve (SFIV). Production packer  94  may be located at a lower end of tubing  88  and landed above the deep set barriers. Upper completion  86  includes a surface controlled subsurface safety valve (SCSSV)  96  located proximate barrier valve  92  in  FIG. 33  to block flow through tubing  88 . Monitoring system  60  may be incorporated with upper completion  86 . For example, sensor  64  may be integrated with tubing  88  to monitor pressure in the area  62  between deep set barrier  114  and shallow set barrier  56 . Sensor  64  may sense pressure in tubing  88  bore and or the tubing-casing annulus. Sensor  64  may be connected to the surface receiver via communication device  66  illustrated as a cable in  FIG. 33 . Shallow set barrier  56  is pressure tested as illustrated by arrows  3  in  FIG. 33 . 
     In  FIG. 34  barrier valve  92  and subsurface safety valve  96  are opened. In  FIG. 35  a deployment tool  40 , for example coil tubing, having an open-close shifting tool  48  and an open only shifting tool  50  is RIH through upper completion  86  opening intermediate barrier valve  44  and lower barrier valve  36 . 
     When deployment tool  40  is pulled out of the hole, open-close shifting tool  48  shifts intermediate barrier valve  44  back to the closed position as illustrated in  FIG. 36 . Upper completion barrier valve  92  is then actuated to the closed position and the well has two barriers in place. Subsurface safety valve  96  may be actuated to the closed position. 
     A suspension plug  100  may be landed in tubing hanger  90  as depicted in  FIG. 37  providing an additional shallow set barrier  102 . The well is suspended in  FIG. 37  with three barriers in place. SID  72  may be removed and the well suspended, as previously described with reference to  FIG. 17 . 
       FIG. 38  illustrates a Christmas tree  104  landed on wellhead  16 . Suspension plug  100  can then be retrieved as illustrated in  FIG. 39 . Upper completion barrier valve  92  is opened in  FIG. 40 . A tubing pressure signal can be applied opening intermediate barrier valve  44  as shown in  FIG. 41 . Barrier valve  44  may be a dual trip saver FIV permitting a second application of pressure to open the valve if the first attempt fails.  FIG. 42  illustrates well  10  on production and producing fluid  110  from formation  9 . 
     Referring now to  FIGS. 43-55 , an open water completion system is described in which dual barrier monitoring systems and methods in accordance to one or more embodiments are implemented. In accordance with an embodiment, a lower barrier is monitored and the lower barrier and the intermediate barrier may not be opened until after installation of a Christmas tree. 
       FIG. 43  illustrates an open water completion system, generally denoted by the numeral  5 , having a subsea well or wellbore  10  drilled from a seabed  12  to an earthen formation  9 . A blowout preventer (BOP) stack  14  has been landed on a wellhead  16  in the depicted well. BOP stack  14  commonly includes one or more sets of each of pipe rams to close on pipe, blind rams to close over an open wellbore, and shear rams to cut the pipe passing through the BOP stack. A marine riser  18  extends from BOP stack  14  to a surface rig  20  located at water surface  22 . Surface rig  20  is illustrated in  FIG. 43  as a platform and marine riser  18  may extend for example one-thousand feet or more through water  7 . In accordance with some embodiments, BOP stack  14  may be located at the top of marine riser  18  and a subsea isolation device may be installed at wellhead  16 . The A-annulus will be formed in casing  24  when the production tubing is installed. 
       FIG. 43  illustrates a lower completion  26  that has been run into the hole (RIH) and landed in a lower section  28  of casing  24  distal from wellhead  16 . Lower completion  26  is illustrated as a sand control completion including a gravel pack packer  30 , tubular  32  (i.e., casing, liner), gravel pack port  34 , and a formation isolation valve (FIV) type of barrier valve  36 . Barrier valve  36  and packer  30  form a lower deep set barrier  112  shown in  FIG. 44 . 
     In  FIG. 44  an intermediate completion  38  has been RIH and mated with lower completion  26  for example as described above with reference to  FIGS. 24-27 . An intermediate or upper deep set barrier  114  is formed by intermediate barrier valve  44  and packer  42 . Lower deep set barrier  112  may be pressure tested prior to closing barrier valve  44 . 
     A sensor  80  and communication device  82  are included in the intermediate completion  38  illustrated in  FIG. 44 . Sensor  80  is in monitoring communication with the area  118  between lower deep set barrier  112  and upper deep set barrier  114 . Sensor  80  senses and monitors at least pressure and may measure additional characteristics including without limitation temperature and flow rate. Deep set sensor  80  is in communication with tubular bore portion of area  118  via port  84  in  FIG. 44 . Communication device  82  is coupled with sensor  80  and is illustrated as a wet connector or induction coupler. Upper deep set barrier  114  is pressure tested as illustrated by the arrow  3 . 
       FIG. 45  illustrates a shallow set barrier  56  landed in casing  24 . Shallow set barrier  56  is landed at a location uphole closer to wellhead  16  than the deep set barrier(s). For example, shallow set barrier  56  is set in the section  58  of the well in which the production completion may be landed. Shallow set barrier  56  is illustrated including a packer  55  and plug  57 . Shallow set barrier  56  may be formed by other devices, such as and without limitation a valve such as a mechanical formation isolation type valve. Three barriers  56 ,  114 ,  112  are in place in  FIG. 45 . 
     The open water completion system  5  includes a monitoring system  60  to at least measure and monitor pressure in the area  62  between shallow set barrier  56  and deep set barrier  114  and to measure and monitor pressure in the area  118  below deep set barrier  114 . Monitoring system  60  includes a shallow set sensor  64  and communication device  66  and deep set sensor  80  and communication device  82 . Sensors  64  and  80  may monitor characteristics in addition to pressure, for example temperature and flow rate. In this embodiment, a wired connector  116  couples deep set sensor  80  to communication device  66 . Wired connector  116  may be RIH with shallow set barrier  56 . Wired connector  116  may be for example E-coil, digital slick line, or wireline having a top coupler  115  connected to communication device  66  and at a bottom coupler  117  connected to communication device  82 . Wired connector  116  may include a structural support, for example a pipe. Communication device  82  may be a wireless type transmitter, for example as previously described with reference to  FIG. 13 . 
     In  FIG. 45  a communication coupler  68  is illustrated RIH from water surface  22  on a deployment  70  and operationally coupled with shallow set communication device  66  thereby connecting sensor  64  and sensor  80  with the surface receiver and controls, for example rig  20 . Deployment  70  may be, for example, wireline or tubing. Any fluctuation in pressure over time could be indicative of a leak in the barriers. In accordance to embodiments, the barriers are independently testable, for example by pressure testing, and independently monitored. 
     Once two independently verifiable barriers are in place the well may be suspended for a period of time, for example six months or more, until additional completion components (e.g. Christmas tree) are installed. Three barriers  56 ,  114 ,  112  are in-place in  FIG. 45 . 
       FIG. 46  illustrates the well  10  suspended and three barriers  112 ,  114 ,  56  in place. BOP stack  14  and marine riser  18  illustrated in  FIG. 45  may be disconnected and removed from wellhead  16 . A subsea or seabed isolation device (SID)  72 , as shown in  FIG. 46 , may be connected to wellhead  16  in place of a BOP stack. 
     After the well has been suspended for a period of time, pressure in area  62  and  118  can be checked to determine if there is a leak. For example, in  FIG. 47  a surface vessel  74  is moved on site and a communication coupler  68  is deployed on a deployment  70  (e.g. tubing, wireline) into the well and connected with monitoring system  60 . Communication coupler  68  is shown in  FIG. 47  deployed through a riser  76  which may be an intervention type or open water type of riser as opposed to a marine riser as utilized during drilling operations. At least the pressure in area  62  between shallow set barrier  56  and the deep set barrier(s) is checked to determine if there is a leak. The pressure in area  118  between the upper deep set barrier  114  and lower deep set barrier  112  can be checked via sensor  80 . After checking the integrity of the barriers, shallow set barrier  56  is retrieved leaving two barriers  112 ,  114  in place as shown in  FIG. 48 . Upper deep set barrier  114 , e.g. barrier valve  44 , is pressure tested as shown by arrows  3 . 
     An upper completion  86 , also referred to as a production completion, is RIH and landed as illustrated for example in  FIG. 49  providing two deep set barriers  112 ,  114  and shallow set barrier  56 . Upper completion  86  can be RIH through SID  72 , for example through an open water or intervention type riser  76  or through open water  7 . Upper completion  86  includes, for example, tubing  88  suspended from a tubing hanger  90  landed at wellhead  16 , and a barrier valve  92 , e.g. formation isolation valve, and a production packer  94 . Shallow set barrier  56  is formed by barrier valve  92  and production packer  94  and is located in the upper section of the well and can be tested independent of the deep set barrier(s). Barrier valve  92  is illustrated in  FIG. 49  as a surface controlled formation isolation valve (SFIV). Production packer  94  may be located at a lower end of tubing  88  and landed above the deep set barriers. Upper completion  86  includes a surface controlled subsurface safety valve (SCSSV)  96  located proximate barrier valve  92  in  FIG. 49 . Monitoring system  60  may be incorporated with upper completion  86 . For example, sensor  64  may be integrated with tubing  88  to monitor pressure in the area  62  between deep set barrier  114  and shallow set barrier  56 . Sensor  64  may sense pressure in tubing  88  bore and or the tubing-casing annulus. Sensor  64  may be connected to the surface receiver via communication device  66  illustrated as a cable in  FIG. 49  and or wirelessly. Shallow set barrier  56  is illustrated being pressure tested by arrows  3 . 
     A suspension plug  100  may be landed in tubing hanger  90  as depicted in  FIG. 50  providing an additional shallow set barrier  102 . Four barriers  102 ,  56 ,  114 ,  112  are in place. SID  72  may be removed and the well suspended as illustrated for example in  FIG. 51 . 
       FIG. 52  illustrates a Christmas tree  104  landed on wellhead  16 . Suspension plug  100  ( FIG. 51 ) has been retrieved. Upper completion barrier valve  92  is opened in  FIG. 53 . A tubing pressure signal can be applied opening intermediate barrier valve  44  as shown in  FIG. 54 . Barrier valve  44  may be a dual trip saver FIV permitting a second application of pressure to open the valve if the first attempt fails. After intermediate barrier valve  44  is open, tubing pressure can be applied to open lower barrier valve  36  as illustrated in  FIG. 55 .  FIG. 55  illustrates well  10  on production and producing fluid  110  from formation  9 . 
     Referring now to  FIGS. 56-68 , an open water completion system is described in which dual barrier monitoring systems and methods in accordance to one or more embodiments are implemented. In accordance with an embodiment, there is monitoring between the barriers and the both lower barriers are opened after the installation of a Christmas tree  104 . 
       FIG. 56  illustrates an open water completion system, generally denoted by the numeral  5 , having a subsea well or wellbore  10  drilled from a seabed  12  to an earthen formation  9 . A blowout preventer (BOP) stack  14  has been landed on a wellhead  16  in the depicted well. A marine riser  18  extends from BOP stack  14  to a surface rig  20  located at water surface  22 . Surface rig  20  is illustrated in  FIG. 56  as a platform and marine riser  18  may extend for example one-thousand feet or more through water  7 . 
       FIG. 56  illustrates a lower completion  26  (e.g. sand control completion) that has been run into the hole (RIH) and landed in a lower section  28  of casing  24  distal from wellhead  16 . Lower completion  26  is illustrated as a sand control completion including a gravel pack packer  30 , tubular  32  (i.e., casing, liner), gravel pack port  34 , and a lower formation isolation valve (FIV) type of barrier valve  36  and a second formation isolation valve  44  which may be referred to from time to time as an intermediate barrier valve  44 . Lower completion  26  includes a sensor  80  in communication with an area  118  between lower barrier valve  36  and intermediate barrier valve  44 . A communication device  82  is coupled with sensor  80  and located above intermediate barrier valve  44  which is located above lower barrier valve  36 . 
     In  FIG. 57  a straddle seal assembly  46 , e.g. port closure sleeve (PCS), is illustrated landed in lower completion  26  and sealing gravel pack port  34 . With gravel pack port  34  sealed a deep set barrier is formed by packer  30  and either of closed barrier valves  36 ,  44 . For example, a lower deep set barrier  112  is formed by packer  30  and lower barrier valve  36  and an upper deep set barrier  114  is formed by packer  30  and upper or intermediate barrier valve  44 . Pressure sensor  80  is in communication with the area  118  located between lower barrier valve  36  and intermediate barrier valve  44 . Area  118  is the internal aria of lower completion  26  between closed barrier valve  36  and closed barrier valve  44  as illustrated in  FIG. 57 . Deep set barrier  114  is pressure tested as illustrated by the arrow  3 . 
       FIG. 58  illustrates a shallow set barrier  56  that has been RIH and landed in casing  24 . Shallow set barrier  56  is landed at a location uphole and closer to wellhead  16  than the deep set barriers. For example, shallow set barrier  56  is set in the section  58  of the well in which the production completion may be landed. Shallow set barrier  56  is illustrated including a packer  55  and plug  57 . Shallow set barrier  56  may be formed by other devices, such as and without limitation a valve such as a mechanical formation isolation type valve. 
     The open water completion system  5  includes a monitoring system  60  to at least measure and monitor pressure in area  62  between the shallow set barrier  56  and deep set barrier  114  to measure and monitor pressure in area  118  between lower and upper barriers  112 ,  114 . Monitoring system  60  includes a shallow set sensor  64  and communication device  66  and deep set sensor  80  and communication device  82 . Sensors  64  and  80  may monitor characteristics in addition to pressure, for example temperature and flow rate. In this embodiment, a wired connector  116  couples deep set sensor  80  to communication device  66 . Wired connector  116  may be RIH with shallow set barrier  56 . Wired connector  116  may be for example E-coil or wireline having a top coupler  115  connected to communication device  66  and at a bottom coupler  117  connected to communication device  82 . Wired connector  116  may include a structural support, for example a pipe. Communication device  82  may be a wireless type transmitter, for example as previously described with reference to  FIG. 13 . 
     In  FIG. 58  a communication coupler  68  is illustrated RIH from water surface  22  on a deployment  70  and operationally coupled with shallow set communication device  66  thereby connecting sensor  64  and sensor  80  with the surface controls, for example rig  20 . Deployment  70  may be, for example, wireline or tubing. Any fluctuation in pressure over time could be indicative of a leak in the barriers. In accordance to embodiments, at least two barriers are independently testable, for example by pressure testing, and independently monitored. 
     Once two independently verifiable barriers are in place the well may be suspended for a period of time, for example six months or more, until additional completion components (e.g. Christmas tree) are installed. Three barriers are in-place in  FIG. 58 . 
       FIG. 59  illustrates the well suspended and two deep set barriers  112 ,  114  and shallow set barrier  56  in place. BOP stack  14  and marine riser  18  illustrated in  FIG. 58  have been disconnected and removed from wellhead  16 . A subsea or seabed isolation device (SID)  72 , as shown in  FIG. 59 , may be connected to wellhead  16  in place of a BOP stack. 
     After the well has been suspended for a period of time the pressure in areas between the barriers is checked to determine if there is a leak. For example, in  FIG. 60  a surface vessel  74  is moved on site and a communication coupler  68  is deployed on a deployment  70  (e.g. tubing, wireline) into the well and connected with monitoring system  60 . Communication coupler  68  may be deployed through open water  7 . At least the pressure in area  62  between shallow set barrier  56  and upper deep set barrier  114  is checked to determine if there is a leak. The pressure in area  118  between the deep set barriers  112 ,  114  can be checked via sensor  80 . After checking the integrity of the barriers, shallow set barrier  56  is retrieved. Upper deep set barrier  114  is pressure tested as shown by arrows  3  in  FIG. 61 . 
     An upper completion  86 , also referred to as a production completion, is RIH and landed as illustrated for example in  FIG. 62  providing a shallow set barrier  56 . Upper completion  86  can be RIH through SID  72 , for example through an open water or intervention type riser or through open water  7 . Upper completion  86  includes, for example, tubing  88  suspended from a tubing hanger  90  landed at wellhead  16 , and a barrier valve  92 , e.g. formation isolation valve, and a production packer  94 . Shallow set barrier  56  is formed by barrier valve  92  and production packer  94  and is located in the upper section  58  of the well and can be tested independent of deep set barriers. Barrier valve  92  is illustrated in  FIG. 62  as a surface controlled formation isolation valve (SFIV). Production packer  94  may be located at a lower end of tubing  88  and landed above deep set barriers  112 ,  114 . 
     Upper completion  86  includes a surface controlled subsurface safety valve (SCSSV)  96  located proximate barrier valve  92 . Monitoring system  60  may be incorporated with upper completion  86 . For example, sensor  64  may be integrated with tubing  88  to monitor pressure in area  62  between shallow set barrier  56  and deep set barrier  114 . Sensor  64  may sense pressure in tubing  88  bore and or the tubing-casing annulus. Sensor  64  may be connected to the surface receiver via communication device  66  illustrated as a cable in this example. Shallow set barrier  56  is illustrated, by arrows  3 , being pressure tested. 
     A suspension plug  100  may be landed in tubing hanger  90  as depicted in  FIG. 63  providing an additional shallow set barrier  102 . Four barriers  102 ,  56 ,  114 ,  112  are in place in  FIG. 63 . SID  72  may be removed and the well suspended, as illustrated for example in  FIG. 64 . 
       FIG. 65  illustrates a Christmas tree  104  landed on wellhead  16 . Christmas tree  104  may be landed and installed through open water  7 . Suspension plug  100  ( FIG. 64 ) has been retrieved. In  FIG. 66  upper completion barrier valve  92  and subsurface safety valve  96  have been opened. 
     In  FIG. 67  intermediate barrier valve  44  is illustrated open after applying a tubing pressure signal.  FIG. 68  illustrates lower barrier valve  36  open after a tubing pressure signal was applied placing well  10  on production permitting fluid  110  to flow. In accordance with some embodiments, intermediate FIV barrier valve  44  and lower FIV barrier valve  36  may be opened at the same time. 
     Referring now to  FIGS. 69 to 89 , in some embodiments the space between the barriers may be monitored with sensors and inductive couplers positioned behind the casing. In  FIG. 69  a well  10  is drilled and casing  24  installed. Casing  24  may include one or more indexing casing coupling (ICC)  120  locators and a communication and sensing system, generally denoted by the numeral  122 , installed behind casing  24 . The behind casing communication system  122  includes a primary inductive coupler  124  or station  124  located uphole, for example, closer to wellhead  16  than to formation  9 , for connecting with a service inductive coupler positioned in the well. Primary inductive coupler  124  is connected via an electrical conductor  126  to one or more sensors and secondary inductive couplers located behind casing  24  and downhole from primary inductive coupler  124 . For example, in  FIG. 69  primary inductive coupler  124  is connected to spaced apart sensors  128 ,  228 ,  328 . In the illustrated embodiment, sensors  128 ,  228 ,  328  read at least pressure inside of casing  24  (i.e., in well  10 ). Communication system  122  may also include sensors that measure for example pressure outside of casing  24  (e.g. the B-annulus). Sensors  128 ,  228 ,  328 , etc. may be WellNet (Schlumberger Limited) type sensors for example.  FIG. 69  illustrates a BOP stack  14 , e.g. drilling BOP, connected to wellhead  16  at seabed  12  and a marine riser  18  extending between BOP stack  14  and rig  20  located at water surface  22 . 
     In  FIG. 70  a lower completion  26  is RIH and landed in lower section  28  of casing  24  and well  10 . Lower completion  26  is set with packer  30  engaging casing  24 . ICC  120  may be utilized to locate and set packer  30  in the desired position. Sensor  128  is located below packer  30  and may be utilized for example to monitor the reservoir pressure and temperature.  FIG. 71  illustrates intermediate completion  38  being RIH on a deployment tool  40  with the intermediate barrier valve  44 , for example a dual trip saver FIV, in the open position. In accordance with some embodiments, deployment tool  40  includes a service inductive coupler  130  ( FIG. 72 ) in communication with a surface receiver, represented by rig  20 , via communication line  132 . 
     In  FIG. 72  intermediate completion  38  is landed on, or mated with, the lower completion such that gravel pack port  34  is sealed for example by straddle seal assembly  46 . Packer  30  and barrier valve  36  form a lower deep set barrier  112  with gravel pack port  34  sealed. Behind casing sensor  128  is set to monitor at least pressure, i.e. reservoir pressure, in the area  134  below lower deep set barrier  112 . Lower deep set barrier  112  can be pressure tested to ensure sealing integrity. 
     A ball  52  ( FIG. 73 ) is dropped and fluid can be pumped through deployment tool  40  to set intermediate packer  42  in sealing engagement with casing  24 . In  FIG. 74  deployment tool  40  is retrieved to a position coupling male service inductive coupler  130  with primary inductive coupler  124 . Shifting tool  48  closes intermediate barrier valve  44  as deployment tool  40  is raised. Intermediate packer  42  and barrier valve  44  form an upper deep set barrier  114 . 
     Still referring to  FIG. 74 , upper deep set barrier  114  is pressure tested as illustrated by the arrows  3 . Monitoring system  60  provides for pressure monitoring in well  10  and between barriers  112  and  114  during pressure testing. Male service inductive coupler  130  is communicatively coupled with primary inductive coupler  124  thereby coupling the surface receiver, e.g. rig  20 , with sensors  128 ,  228 ,  328 . Sensor  128  is in sensing communication with area  134  below lower deep set barrier  112  and sensor  228  is in sensing communication with area  118  between lower deep set barrier  112  and upper deep set barrier  114 . Sensor  328  is in sensing communication with area  62  above upper set barrier  114 . 
       FIG. 75  illustrates the well after the deployment tool has been retrieved and with two barriers  112 ,  114  in place. Lower deep set barrier  112  and upper deep set barrier  114  are each independently tested and each may be monitored independently. In  FIG. 76  an operator comes back and RIH and installs a shallow set barrier  56 , for example including a plug or packer  55  and mechanical formation isolation barrier valve  59 , in upper completion section  58 . A communication coupler  68 , for example a male service inductive coupler, is RIH and mated with primary inductive coupler  124  and at least pressure is checked between the barriers. For example, sensor  128  monitors pressure in area  134  below lower deep set barrier  112 , sensor  228  monitors pressure in area  118  between lower deep set barrier  112  and upper deep set barrier  114 , and sensor  328  monitors pressure in area  62  between shallow set barrier  56  and upper deep set barrier  114 . With the installation of shallow set barrier  56 , the well has three barriers in place and may be suspended. When suspended the BOP stack  14  and marine riser may be removed.  FIG. 77  illustrates the well suspended and with a subsea isolation device  72  connected to wellhead  16 . 
     After the well has been suspended for a period of time an operator, e.g. vessel  74 , comes back to check the pressure integrity of the barriers as illustrated in  FIG. 78 . A communication coupler  68  is RIH and mated with primary inductive coupler  124  and the pressure in area  62  between shallow set barrier  56  and upper deep set barrier  114  and the pressure in area  118  between upper deep set barrier  114  and lower deep set barrier  112  is checked. Confirming pressure integrity, shallow set barrier  56  is removed from the well as illustrated in  FIG. 79 . Two barriers  112 ,  114  remain in place. 
     In  FIG. 80  a production or upper completion  86  is RIH and tubing  88  is suspended from wellhead  16  by tubing hanger  90  and production packer  94  is set. Upper completion  86  includes a monitoring system  60  that includes male service inductive coupler  130  mated with primary inductive coupler  124  and sensor  64  in monitoring communication with area  62 . Connection of service inductive coupler  130  with primary inductive coupler  124  provides monitoring communication between the surface receiver, for example vessel  74 , and sensors  128 ,  228  and  328 . Shallow set barrier  92  is pressure tested in  FIG. 80  as shown be the arrows  3 . 
     In  FIG. 81  the upper completion barrier valve  92 , e.g. surface controlled formation isolation valve, is opened. The subsurface safety valve  96  is also opened. In  FIG. 82  a deployment tool  40  is RIH opening intermediate barrier valve  44  and lower barrier valve  36  as previously described for example with reference to  FIG. 35 . When deployment tool  40  is POOH, a shifting tool of the deployment tool shifts intermediate barrier  44  back to the closed position as illustrated in  FIG. 83 . Shallow barrier valve  92  and subsurface safety valve  96  are then actuated to the closed position. 
     In  FIG. 84  a suspension plug  100  is landed in tubing hanger  90  providing an additional shallow set barrier  102 . Barrier  102 , shallow set barrier  56 , and intermediate or upper deep set barrier  114  are in place and the well is prepared to place in suspension. For example, SID  72  may be removed and the well may be suspended as previously described for example with reference to  FIG. 17 or 51 . 
     With reference to  FIGS. 85 to 89 , the well is placed on production. In  FIG. 85  a Christmas tree  104  is landed on wellhead  16 . Suspension plug  100  ( FIG. 85 ) is retrieved through Christmas tree  104  as illustrated in  FIG. 86 . Upper barrier valve  92  is operated to the open position as illustrated in  FIG. 87 . Tubing  88  pressure can then be applied to open intermediate barrier valve  44  as shown in  FIG. 88 . With barrier valves  92 ,  44  and  36  opened, well  10  can produce formation fluid  110  as illustrated in  FIG. 89 . Sensor  228  which was used for monitoring the lower barrier, e.g.  FIG. 76 , can be used to monitor the reservoir  9  pressure and temperature via open communication port  84  ( FIG. 74 ). Similarly, sensor  328  which was utilized to monitor the upper deep set barrier, e.g.  FIG. 76 , can be utilized to monitor the A-annulus. Sensor  128  may be utilized for example for permanent reservoir  9  monitoring. 
     Referring now to  FIGS. 90 to 103 , an embodiment of an open water barrier completion and monitoring system and method is described. In some embodiments of an open water completion system  5  a gravel pack system may be run as part of a lower completion. Lower completion  136  includes at least two packers  30 ,  138 , two barrier valves  44 ,  36  and a sensor  80  to measure pressure outside of lower completion  136  and inside of casing  24 . In accordance to one or more embodiments, sensor  80  includes a communication device  82 , illustrated as a female inductive coupler. Intermediate barrier valve  44  is positioned between upper packer  30  and lower packer  138 . Lower barrier valve  36  is located below lower packer  138 . In the depicted embodiments, upper packer  30  seals with the casing and includes slips  144  to engage casing  24  and provide mechanical support. Lower packer  138  does not have slips and will provide a seal but not mechanical support. During gravel packing operations lower packer  138  is not set, hence, gravel packing fluid and slurry can be pumped between casing  24  and lower packer  138 . 
       FIG. 90  illustrates the well during gravel packing Upper packer  30  is set in casing  24  to provide an annular seal and support lower completion  136 . Lower packer  138  has not been set. A deployment tool  40  (e.g. service tool) is illustrated RIH and deployed through lower completion  136 . Gravel pack port  34 , located between upper packer  30  and barrier valve  44 , is open in  FIG. 90 . A port  84  through tubular  32  is closed by a sleeve  146 . 
     Gravel pack slurry is pumped from the interior of lower completion  136  through gravel pack ports  34  to the exterior, i.e. annulus,  148  of lower completion  136 . The slurry can then flow between casing  24  and lower packer  138  toward formation  9 . This gravel pack operation may occur with the service tool deployed through the interior of the gravel pack assembly. 
     When the gravel pack operation is completed, service tool  40  may be picked up as illustrated in  FIG. 91  and in the process the service tool may shift the lower FIV barrier valve  36  closed and open a pressure communication port  154  on lower packer  138 . In accordance to an embodiment, PCS shifting tool  150  closes gravel pack port  34  with port closure sleeve  46 , e.g. straddle seal assembly, and shifting tool  152  opens pressure communication port  154  of lower packer  138 . 
     Referring to  FIG. 92 , pressure may then be raised as illustrated by arrows  3  in the interior of the gravel pack completion  136  assembly to test the seal of lower FIV barrier valve  36  and to set lower packer  138  via the opened pressure communication port  154  ( FIG. 91 ). Lower barrier valve  36  and set lower packer  138  provide a lower deep set barrier  112 . Lower deep set barrier  112  may be pressure tested. 
     Deployment tool  40  may be picked up further as shown in  FIG. 93  moving sleeve  146  and opening port  84 . As deployment tool  40  is further picked up, as illustrated in  FIG. 94 , intermediate barrier valve  44  is closed leaving two barriers in place. Intermediate barrier valve  44  may be pressure tested. 
     Opening of port  84  provides communication between the interior  135  of lower completion  136  between barrier valves  36 ,  44  and exterior  148  between upper packer  30  and lower packer  138 . This area is also referred to as the area  118  between the lower deep set barrier and the upper deep set barrier. Sensor  80  is in communication with area  118 . 
       FIG. 95  shows well  10  with lower deep set barrier  112  and upper deep set barrier  114  in place. Upper deep set barrier  114  is formed by packer  30  and intermediate barrier valve  44 . Sensor  80  is in monitoring communication with area  118  between lower deep set barrier  112  and upper deep set barrier  114 . 
     In  FIG. 96  a shallow set barrier  56  is installed in the upper completion section  58  of the well providing three barriers. In this example, shallow set barrier  56  includes shallow set sensor  64  for measuring pressure in area  62  between shallow set barrier  56  and deep set barrier  114 . As previously described for example with reference to  FIG. 45 , monitoring system  60  may include a wired connector  116  coupling deep set sensor  80  with the shallow set communication device  66  which is shown as an inductive coupler or wet connect. Wired connector  116  may be a wire, E-coil, cable or the like and connector  116  may include or may not include a structural support member such as pipe. A top coupler  115  is connected to shallow set communication device  66  and lower coupler  117 , e.g. male induction coupler, is connected with deep set communication device  82 . A communication coupler  68  is shown RIH and mated with shallow set communication device  66  thereby connecting the surface receiver, e.g. rig  20 , with sensor  64  and sensor  80 . 
       FIG. 97  illustrates the well suspended with three barriers in place. BOP stack  14  ( FIG. 96 ) is removed and replaced with a subsea or seabed isolation device  72 . The integrity of barriers  56 ,  114 ,  112  may be checked periodically. At  FIG. 98  a smaller vessel  74  is moved on site to check the integrity of the barriers. It is not necessary to deploy a rig. As described for example with reference to  FIG. 96 , a communication coupler  68  is deployed for example through open water  7  and SID  72  and connected with communication device  66  of monitoring system  60 . The integrity of the barriers can be checked by monitoring the pressure in area  62  via sensor  64  and area  118  via sensor  80 . After checking the integrity of the barriers, shallow set barrier  56  is retrieved leaving two barriers  112 ,  114  in place as shown in  FIG. 99 . Upper deep set barrier  114  is pressure tested as shown by arrows  3  in  FIG. 99 . 
     When the well is ready, an upper completion  86  may be RIH and installed as shown in  FIG. 100 . For example, upper completion  86  may include a tubing  88 , production packer  94 , a surface controlled subsurface safety valve  96 . Tubing  88  is suspended from a tubing hanger  90 . A suspension plug  100  is coupled with tubing hanger  90  to form a shallow set barrier  102 . A sensor  64  is in communication with the area  62  between shallow set barrier  102  and intermediate barrier  114 . Once upper completion  86  is installed, SID  72  can be removed as illustrated in  FIG. 101  leaving three barriers  102 ,  114 ,  112  in place. 
     In  FIG. 102  a Christmas tree  104  is installed and the suspension plug is removed. In  FIG. 103  tubing pressure has been applied to open barrier valves  36 ,  44 . Formation fluid  110  can then be produced. 
     Referring now to  FIGS. 104-117 , in some embodiments, prior to the installation of the lower completion (e.g. gravel pack assembly) or the upper completion, a female inductive coupler and at least two pressure or temperature gauges may be installed behind the casing. Deploying the shallow set plug below the primary behind casing female inductive coupler, but above the behind casing pressure/temperature gauge, allows the behind casing pressure/temperature gauge to monitor conditions between the shallow set barrier, e.g. plug, and the upper deep set FIV valve, to determine integrity and well conditions. Once the shallow set plug is set, the gauges may have power and communication supplied to them by deploying a service inductive coupler portion, for example on wireline, to provide power and communication from the surface, and to communicate through induction principles, with the female inductive coupler and gauges deployed behind the casing. 
     In  FIG. 104  a well  10  is drilled and casing  24  installed. Casing  24  may include one or more indexing casing coupling locators and a communication and sensing system, generally denoted by the numeral  122 , installed behind casing  24 . The behind casing communication system  122  includes a primary inductive coupler  124  or station  124  located uphole, for example in the upper completion section closer to wellhead  16  than to formation  9 , for connecting with a service inductive coupler positioned in the well. Primary inductive coupler  124  is connected via an electrical conductor  126  to one or more sensors and secondary inductive couplers located behind casing  24  and downhole from primary inductive coupler  124 . For example, in  FIG. 104  primary inductive coupler  124  is connected to spaced apart sensors  228 ,  328 . In the illustrated embodiment, sensors  228 ,  328  read at least pressure inside of casing  24  (i.e., in well  10 ). Communication system  122  may also include sensors that measure for example pressure outside of casing  24  (e.g. the B-annulus). Sensors  228 ,  328 , etc. may be WellNet (Schlumberger Limited) type sensors for example. A BOP stack  14 , e.g. drilling BOP, is depicted connected to wellhead  16  at seabed  12  and a marine riser  18  extending between BOP stack  14  and rig  20  located at water surface  22 . 
       FIG. 105  illustrates a lower completion  136  installed in the well and gravel packing the well. The depicted lower completion  136  includes at least two packers  30 ,  138 , and two barrier valves  44 ,  36 . Lower completion  136  is landed in the well with sensor  228  located between upper packer  30  and lower packer  138 . Intermediate barrier valve  44  is positioned between upper packer  30  and lower packer  138 . Lower barrier valve  36  is located below lower packer  138 . In the depicted embodiments, upper packer  30  seals with the casing and includes slips  144  to engage casing  24  and provide mechanical support for lower completion  136 . Lower packer  138  does not have slips and will provide a seal but not mechanical support. 
     A deployment tool  40  (e.g. service tool) is RIH and deployed through lower completion  136 . Gravel pack port  34 , located between upper packer  30  and barrier valve  44  is open. A port  84  through tubular  32  is closed in  FIG. 105  by sleeve  146 . Gravel packing slurry can be pumped from interior  135  of the lower completion through gravel pack port  34  to exterior  148  (e.g. annulus) between completion  136  and casing  24 . The slurry can then flow between casing  24  and lower packer  138  toward formation  9 . 
     When the gravel pack operation is completed, service tool  40  may be picked up as illustrated in  FIG. 106 . As the service tool is picked up the lower FIV barrier valve  36  is shifted closed and pressure communication port  154  of lower packer  138  is opened. In accordance to an embodiment PCS shifting tool  150  closes gravel pack port  34  with port closure sleeve  46 , e.g. straddle seal assembly, and shifting tool  152  opens pressure communication port  154  of lower packer  138 . 
     Referring to  FIG. 107  pressure may then be raised as illustrated by arrows  3  in the interior of the gravel pack completion  136  assembly to test the seal of lower FIV barrier valve  36  and to set lower packer  138  via the opened pressure communication port  154  ( FIG. 106 ). Lower barrier valve  36  and set lower packer  138  provide a lower deep set barrier  112 . Lower deep set barrier  112  may be pressure tested. Service tool  40  may include a service inductive coupler, for example as previously described with reference to  FIGS. 72-74 , that is connectable with behind casing sensors  228 ,  328  via primary inductive coupler  124 . 
     Deployment tool  40  may be picked up as shown in  FIG. 108  moving sleeve  146  and opening port  84 . Opening port  84  provides communication between the interior  135  of completion  136  and exterior  148  between upper packer  30  and lower packer  138 . As deployment tool  40  is further picked up, as illustrated in  FIG. 109 , intermediate barrier valve  44  is closed leaving two barriers in place. Intermediate barrier valve  44  may be pressure tested. 
     Barrier  114  is formed by closed barrier valve  44  and upper packer  30 . Opening of port  84  provides communication between the interior  135  of lower completion  136  between barrier valves  36 ,  44  and exterior  148  between upper packer  30  and lower packer  138 . This area is also referred to as area  118  between lower deep set barrier  112  and upper deep set barrier  114 . Behind casing sensor  228  is in sensing and monitoring communication with area  118 . 
       FIG. 110  illustrates well  10  after service tool  40  has been pulled out of the hole leaving two barriers  112 ,  114  in place. Each of barriers  112 ,  114  may have been independently tested to verify seal integrity. Sensor  228  is in monitoring communication with area  118  between deep set barriers  112 ,  114  and sensor  328  is in monitoring communication with area  62  above the deep set barriers. Behind casing monitoring system  122  provides for continuous and periodic pressure monitoring of barriers  112 ,  114 . 
     In  FIG. 111  a shallow set barrier  56 , for example including a packer  55  and plug  57 , is installed in the well uphole from deep set barriers  114 ,  112  in the production completion section  58 . A communication coupler  68 , for example a male service inductive coupler, is RIH and mated with primary inductive coupler  124  and at least pressure is checked between the barriers. For example, sensor  228  monitors pressure in area  118  between lower deep set barrier  112  and upper deep set barrier  114 , and sensor  328  monitors pressure in area  62  between shallow set barrier  56  and upper deep set barrier  114 . Additional sensors may be included, for example, to monitor pressure below lower deep set barrier  112 . 
     With the installation of shallow set barrier  56 , the well has three barriers in place and may be suspended. BOP stack  14  and marine riser may be removed.  FIG. 112  illustrates the well suspended and with a subsea isolation device  72  connected to wellhead  16  in place of the BOP stack. 
     After the well has been suspended for a period of time an operator may come back to check the pressure integrity of the barriers for example as previously described with reference to  FIG. 78 . Confirming pressure integrity, shallow set barrier  56  is removed from the well and a production completion  86  may be run-in-hole and installed as illustrated for example in  FIG. 113 . For example, upper completion  86  may include a tubing  88 , production packer  94 , a surface controlled subsurface safety valve  96 . Tubing  88  is suspended from a tubing hanger  90 . A suspension plug  100  is coupled with tubing hanger  90  to form a shallow set barrier  102 . A sensor  64  is in communication with area  62 , for example tubing bore area, between shallow set barrier  102  and intermediate barrier  114 . Behind casing sensor  328  is in communication with area  62 , for example tubing-casing annulus section, between shallow set barrier  102  and barrier  114 . 
     As illustrated for example in  FIG. 117  and as previously described with reference to  FIGS. 80-89 , upper completion  86  may include a coupler  130  to couple behind casing monitoring system  122  with the surface receiver. For example, with reference to  FIGS. 117 and 80-89 , coupler  130  may be a male service induction coupler incorporated with upper completion  86 . Connection of service inductive coupler  130  with primary inductive coupler  124  provides monitoring communication between the surface receiver, for example subsurface station or surface vessel, and sensors  228  and  328 . 
     Once upper completion  86  is installed, SID  72  can be removed as illustrated in  FIG. 114  leaving three barriers  102 ,  114 ,  112  in place. The well can be suspended as illustrated in  FIG. 114  until it is desired to place the well on production. In  FIG. 115  a Christmas tree  104  is installed and the suspension plug is removed. In  FIG. 116  tubing pressure has been applied to open barrier valves  36 ,  44  and place the well on production. Formation fluid  110  can then be produced. 
     Referring now to  FIGS. 118 to 120 , in some embodiments the monitoring of the well integrity may occur by providing an acoustic signal transmitter assembly in a gravel pack assembly for example. The deep set acoustic signal transmitter assembly may include a battery, electronics and pressure/temperature gauge for reading conditions between the barriers. In these embodiments, the shallow set barrier may include a receiver and transmitter device that is suitable to receive the signal from the lower deployed, e.g. deep set, acoustic signal transmitter. The shallow set transmitter is also suitable to transmit an acoustic signal to the surface, which may be monitored by a surface vessel. Acoustic signals may be, for instance, tube wave type signals. 
     Referring first to  FIG. 118  a lower completion  136  is illustrated in installed in well  10 . Lower completion  136  can be installed in the well as previously described with reference to  FIGS. 90 to 95 . Sensor  80  of lower completion  136  is in communication with area  118  between lower deep set barrier  112 , i.e. FIV barrier valve  36 , and upper deep set barrier  114 , e.g. FIV barrier valve  44 . As previously described, sensor  80  may be measuring the pressure in the annulus outside of the lower completion which is in communication with the interior of the lower completion through the port  84 . The integrity of lower deep set barrier  112  can be monitored and confirmed via deep set sensor  80 . 
     In accordance with one or more embodiments, sensor  80  includes a communication device  82 . For example, sensor  80  may be an assembly including the gauging elements and communication elements. In this example, communication device  82  is a wireless telemetry transmitter module and may include a local power source, e.g. battery. 
     Communication device  82  may transmit for example via wireless data transfer or tube wave in the casing fluid column to a surface receiver, for example rig  20  or seabed station  108  ( FIG. 120 ). In accordance to some embodiments, communication device  82  wirelessly transmits the data to shallow set communication device such as described with reference to  FIGS. 11, 13, and 120 . 
     A shallow set barrier  56  is depicted in  FIG. 119  installed in the well in the upper completion section  58 . In this example, shallow set barrier  56  includes a sensor  64  and communication device  78 , which may be assembled together in a module. Sensor  64  is in monitoring communication with area  62  between shallow set barrier  56  and upper deep set barrier  114 . Communication device  78  may include electronics and a stand along power source. Communication device  78  is configured to wirelessly transmit data from sensor  64  and sensor  80  to a surface receiver, for example rig  20  in  FIG. 119 , and vessel  74  or seabed station  108  in  FIG. 120 . Three barriers  56 ,  114 ,  112  are in place and the well may be suspended for example as illustrated in  FIG. 120 . Suspended open water completion system  5  may be continuously or periodically monitored as illustrated for example in  FIG. 120 . Sensor  64  may sense pressure as well as other characteristics in area  62 . Communication device  78  can transmit sensor  80  data wirelessly to the surface receiver. Fluctuation in pressure for example can indicate a leak in upper deep set barrier  114 . Sensor  80  gauges pressure in area  118  and communication device  82  can wirelessly transmit the sensor  80  data to shallow set communication device  78  and transmitted to the surface receiver. Fluctuations in pressure in area  118  can indicate a leak in lower deep set barrier  112  for example. 
     The foregoing outlines features of several embodiments of dual barrier open water completion systems so that those skilled in the art may better understand the aspects of the disclosure. Those skilled in the art should appreciate that they may readily use the disclosure as a basis for designing or modifying other processes and structures for carrying out the same purposes and/or achieving the same advantages of the embodiments introduced herein. Those skilled in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the disclosure, and that they may make various changes, substitutions and alterations herein without departing from the spirit and scope of the disclosure. The scope of the invention should be determined only by the language of the claims that follow. The term “comprising” within the claims is intended to mean “including at least” such that the recited listing of elements in a claim are an open group. The terms “a,” “an” and other singular terms are intended to include the plural forms thereof unless specifically excluded.