US20110192596A1

US20110192596A1 - Through tubing intelligent completion system and method with connection

Info

Publication number: US20110192596A1
Application number: US13/021,744
Authority: US
Inventors: Dinesh R. Patel
Original assignee: Schlumberger Technology Corp
Current assignee: Schlumberger Technology Corp
Priority date: 2010-02-07
Filing date: 2011-02-05
Publication date: 2011-08-11
Also published as: NO20110206A1

Abstract

A technique facilitates use of a through tubing completion system run in a lateral borehole. The through tubing completion may comprise production tubing coupled to a flow control valve and one or more sensors measuring at least one characteristic of the lateral borehole. The through tubing completion also comprises a connection system which facilitates the transfer of signals between the through tubing completion extending into the lateral borehole and a surface location or other location.

Description

CROSS-REFERENCE TO RELATED APPLICATION

The present document is based on and claims priority to U.S. Provisional Application Ser. No. 61/302,138, filed Feb. 7, 2010; to U.S. Provisional Application Ser. No. 61/302,137, filed Feb. 7, 2010; and to U.S. Provisional Application Ser. No. 61/302,232, filed Feb. 8, 2010.

BACKGROUND

1. Field of the Invention
The present invention relates generally to well completion systems, and more particularly to through tubing intelligent completion systems. However, identification of an exemplary field is for the purpose of simplifying the detailed description and should not be construed as a limitation. Various embodiments of the concepts presented herein may be applied to a wide range of applications and fields as appropriate.
2. Description of the Related Art
The following descriptions and examples are not admitted to be prior art by virtue of their inclusion in this section.
When an existing oil well begins to become depleted or water out, there exists a need to close off or choke off the formerly producing formation and drill a secondary leg. The secondary leg may be drilled in the same well to a new pocket of oil and/or gas. Generally, the secondary leg may be referred to as a lateral or multi-lateral leg. This process of drilling a lateral leg is required in order to rejuvenate a producing oil well without the considerable costs and expense of drilling a completely new well.
Often, these new lateral legs are drilled while the existing completion string remains in place. This type of drilling may be referred to as through tubing drilling or coiled tubing drilling. Through tubing drilling creates new drainage points in laterals or a series of laterals, often called multi-laterals. With this type of well construction, there are challenges with respect to completing these new drainage points due to the constraints posed by the existing upper completion sections. The existing upper completion sections generally reduce the through hole diameter of the well system available to run a through tubing completion. Additionally, another challenge is communicating with the through tubing completion in order to achieve selective control and data measurement. Of course, other challenges exist beyond these listed examples and may be addressed by this disclosure.

SUMMARY

Embodiments of the claimed system or methodology may comprise a through tubing completion system run in a lateral borehole. The through tubing completion may comprise production tubing coupled to a flow control valve and one or more sensors measuring at least one characteristic of the lateral borehole. In addition, the through tubing completion may comprise one of a male or female wet connect system configured to communicatively couple with the flow control valve and the one or more sensors. A corresponding one of the male or female wet connect system may be placed in communication with the one of the male or female wet connect system to control the flow control valve and/or to communicate the at least one characteristic of the lateral borehole.
In other embodiments, the connection system may comprise a wireless communications module configured to wirelessly communicate with a surface location while coupled to an upper portion of the through tubing completion. In some embodiments, the through tubing completion may comprise a wireless communication link configured to wirelessly communicate with a surface location across a gap. In this latter example, the wireless communication link may comprise a coil arrangement to inductively communicate across the gap. Embodiments of the claimed disclosure also may comprise a method for installing a through tubing completion system with the connection system.
Other or alternative features will become apparent from the following description, from the drawings, and from 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 drawings illustrate only the various implementations described herein and are not meant to limit the scope of various technologies described herein. The drawings are as follows:

FIG. 1 is a schematic illustration of a through tubing completion with a wet mate connector, according to an embodiment of the disclosure;

FIG. 2 is a schematic illustration of a portion of a through tubing completion with an inductive wet mate connector, according to an embodiment of the disclosure;

FIG. 3 is a schematic illustration of a portion of a through tubing completion with a retrievable connector, according to an embodiment of the disclosure;

FIG. 4 is a schematic illustration of a through tubing completion with a hydraulic and electric wet mate connector, according to an embodiment of the disclosure;

FIG. 5 is a schematic illustration of a through tubing completion with a wireless communication link to the surface, according to an embodiment of the disclosure;

FIG. 6 is a schematic illustration of a through tubing completion with a short hop wireless communication link to the surface, according to an embodiment of the disclosure;

FIG. 7 is a schematic illustration of a through tubing completion with a seismic/acoustic wireless communication link to the surface, according to an embodiment of the disclosure;

FIG. 8 is a schematic illustration of a through tubing completion with a wireless communications link to the surface, according to an embodiment of the disclosure;

FIG. 9 is a schematic illustration of communication coils employed in the wireless communications link illustrated in FIG. 8, according to an embodiment of the disclosure;

FIG. 10 is a schematic illustration of a through tubing completion with a wireless communications link to the surface, according to another embodiment of the disclosure; and

FIG. 11 is a schematic illustration of communication coils employed in the wireless communications link illustrated in FIG. 10, according to an embodiment of the disclosure.

DETAILED DESCRIPTION

In the following description, numerous details are set forth to provide an understanding of some illustrative embodiments of the present invention. However, it will be understood by those skilled in the art that various embodiments of the present invention 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 “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 invention.
Embodiments of this disclosure generally relate to a side track or a lateral drilled from an existing completion, referred to as through tubing drilling. Additionally, embodiments also relate to how a side track or lateral bore can be completed without pulling the existing completion and without or with minimal modification of the existing surface infrastructure, referred to as through tubing completion. In some embodiments, the through tubing completion systems relate to intelligent completions or completion systems that are adjustable based on conditions arising in the well.
Referring in general to FIGS. 1 and 2, these drawings show an embodiment of a through tubing completion system 20 having a communication connection or coupling system 21 comprising a male coupler wet connect 22 run on a cable 24, according to aspects of the present disclosure. As shown, a well system 26 may comprise an existing upper completion 28 including completion components such as production tubing 30, e.g. 7 inch production tubing, and a surface controlled subsurface safety valve (SCSSV) 32, e.g. a 7 inch valve, for example. The production tubing 30 and SCSSV 32 may be run in a wellbore 34, e.g. a cased wellbore comprising a production casing 36, such as a 9⅝ inch production casing. In the example shown, the annulus between the production tubing 30 and the production casing 36 may be sealed with a production packer 38, e.g. a 9⅝ inch production packer.
When the well becomes depleted or begins to water out, a production deflector, or a “whipstock” 40 may be run within the production tubing 30. The whipstock 40 facilitates a coil tubing or through tubing drilling operation to form a side track or lateral bore 42 to a new productive location. After the lateral bore 42 is formed, the open lateral borehole must be completed to control the flow of production fluid from the borehole. In some embodiments, the lateral borehole 42 may comprise more than one productive zone 44, such as in a multi-zone wellbore. For example, three controllable zones 44 separated by open hole packers 46, e.g. swell packers, are shown in this illustration. In some cases at least one passive inflow control device, or “ICD” monitoring gauges may be run in the lateral.
To complete the lateral bore 42, the components of a through bore completion must be able to pass through the smallest diameter of the existing upper completion 28. In this case, the SCSSV 32 restricts the outer diameter of the through tubing completion to a restricted diameter, e.g. a 5¾ inch diameter. As shown, a through tubing completion 48 is consequently made up of a smaller diameter production tubing 50, such as 4 inch diameter production tubing. The smaller diameter production tubing 50 is sealed to the inner diameter of the larger production tubing 30 via a ported packer 52, e.g. a 7 inch ported packer. The ported packer 52 seals the annulus between the smaller diameter production tubing 50 and the larger, surrounding production tubing 30. An opening 54 is provided above the ported packer 52 to allow fluid to flow from the lateral borehole to the surface via the larger production tubing 30 (the opening may be more clearly seen in FIG. 2).
Included in the illustrated embodiment of a through tubing completion 48 are a number of electrically activated flow control valves (FCV) 56. The valves 56 may be coupled with sensors 58 to measure and transmit one or more lateral borehole parameters, such as flow rate, pressure, temperature, water cut, resistivity, etc. The information may be coupled to a female wet connect 60 provided at the top of the through tubing completion 48. Female wet connect 60 and male wet connect 22 form connection or coupling system 21, which in this case is a wet connect system. In addition, a cable 62 also may provide communication and/or power to individually control each of the downhole electric FCVs 56. Coupled to the female wet connect 60 and the cable 62 is a rechargeable or retrievable battery/power source 64. In this example, the power source 64 may be configured to only provide power to the various downhole sensors 58. Due to the relatively low power draws of the sensors 58, this can help to minimize the size of the power supply 64. Of course, in other embodiments, the power source 64 may be employed to electrically operate the FCVs 56.
To download data, recharge the battery 64, and actuate the FCVs 56, male wet connect 22 may be run in hole on the cable 24. In some cases, the male wet connect 22 may be pulled out of hole (POOH) during production. In other cases, the cable 24 connecting the male wet connect 22 to the surface may be used to provide real time monitoring and control of the lateral bore 42 during periods of production. Additionally, the male and female wet connect 22, 60 may be electrically coupled to each other via inductive or electromagnetic coupling or via electrical contact between the male and female wet connect component.
As illustrated in greater detail in FIG. 2, the male and female wet connect components 22, 60 may be coupled together via a latching mechanism 66. In this embodiment, the wet connect components 22, 60 are shown coupled together via an inductive coupling 68, although the components are not limited to this example. In other cases, the wet connect components 22, 60 may comprise a direct electrical connection. The inductive coupler wet connect system shown may provide one or two way communication of power, signaling, data transmission, or some combination of these. In this particular example, an electronics cartridge 70 is coupled into cable 62 beneath the inductive coupling 68; and electronics 72 are disposed within male wet connect 22.
Turning now to FIG. 3, another embodiment of the wet connect components 22, 60 is illustrated. In this case, the male wet connect 22 comprises a retrievable power source 74 conveyed downhole and coupled to the upper end of the through tubing completion 48. The retrievable power source 74 may be retrieved at periodic times and allows the through tubing completion 48 to be configured with smaller or no permanently attached power supplies. In addition to providing power, the retrievable power supply 74 also may have a storage component 76 for recording data obtained by the sensors 58. Once retrieved to the surface, the data may be downloaded and processed for future well system control.
The retrievable power source 74 also may be used during production. Fluid may flow from the smaller through tubing completion, e.g. completion 48, to the larger existing production tubing, e.g. upper completion 28, as indicated by the arrows 78 in the figure. Power and control of the electronic FCVs 56 (not shown in this figure) may take place autonomously downhole or via wireless signaling.
Referring generally to FIG. 4, another embodiment of the through tubing completion system 20 is illustrated. In this embodiment, the through tubing completion system 20 comprises a through tubing completion 48 similar to the through tubing completion described with regards to FIG. 1. Therefore, in the interest of reducing the overall length of the disclosure, only the differences will be explained in detail. Instead of the wet connect system primarily communicating electrical power and/or signals, this embodiment has a connection system 21 comprising a hydraulic and electrical wet connect system 80. The electrical components 82 of the wet connect system 80 may communicate electrical power and/or signals via inductive or direct electrical contact. However, in addition to the electrical components 82, there are hydraulic components 84 of the wet connect system 80. The hydraulic components 84 couple to the top of the through tubing completion 48 and provide hydraulic power to the FCVs 56. In this case, hydraulic FCVs are provided in the various production zones 44 of the lateral borehole 42. The hydraulic and electrical wet connect system 80 may be hydraulically and electrically coupled to the surface of the well system via a hybrid cable 86 comprising hydraulic and electric conduits 88, 90, respectively.
The hydraulic component 84 of the wet connect system 80 may be used to provide an adjustment to the hydraulic FCVs 56. The use of hydraulic FCVs eliminates the need for relatively large permanent, retrievable, or rechargeable power supplies. In addition, the open hole packers 46 (if not electrically set or swell packers) may be hydraulically set after running the through tubing completion into the lateral bore. In some cases, a male hydraulic wet connect 92 may be disengaged from a female hydraulic wet connect 94 and pulled out of hole during production of the lateral bore 42.
Referring in general to FIG. 5, another embodiment of the through tubing completion system 20 is illustrated. In this embodiment, system 20 comprises a retrievable communications module 96. The retrievable communications module 96 may comprise a wireless telemetry module 98, a male inductive coupler 100 of inductive coupling 68, a downhole power storage/generator module 102, and/or other suitable components. The retrievable communications module 96 may be sent downhole and coupled to the top of the through tubing completion 48.
Power and data may be communicated between the retrievable communications module 96 and the through tubing completion 48 via the male inductive coupler 100 and a corresponding female inductive coupler 104 of the wet connect connection system 21. Although male and female inductive couplers 100, 104 are shown as establishing a power and/or communication pathway between the retrievable communications module 96 and the rest of the through tubing completion 48, other embodiments may comprise other forms of wet connect (i.e., establishing power/control links downhole) to couple the retrievable communications module 96 and the through tubing completion 48 together. For example, in some cases the wet connect may include electrical terminals in direct contact with one another. In addition, the male inductive coupler 100 of the retrievable communications module 96 and the female inductive coupler 104 may be engaged together via a latching mechanism, such as latching mechanism 66.
As described above, the retrievable communications module 96 may include downhole power generation and/or storage module 102. The power provided by module 102 of the retrievable communications module 96 may be used to power the sensors 58, electrical flow control valves 56, and the wireless communications module 98. The capacity and configuration of the power module 102 may be determined based on the number of electrical components to energize and on a desired replacement rate. The power storage of module 102 may comprise batteries, capacitors or other forms of power storage. In some embodiments, module 102 comprises power generation capability.
As illustrated in FIG. 5, this configuration of the retrievable communications module 96 comprises a bore 106 to allow the flow through of production fluid when the retrievable communications module 96 is in place. Accordingly, module 102 may comprise a power generator device 108 such as a turbine to generate power from the fluid flowing through the retrievable communications module 96. At various predetermined intervals or when indicated via a sensor, the retrievable communications module 96 may be retrieved and replaced to provide for future operation of the through tubing completion.
Data obtained by the sensors, e.g. sensors 58, may be transmitted via the cable 62 to the inductive coupler system 68 (i.e., the male and female inductive couplers 100, 104). From the inductive coupler system 68, the data may be sent to the wireless telemetry module 98. The wireless telemetry module 98 may be configured to transmit data and control signals between the surface and the through tubing completion 48 via a corresponding wireless telemetry module 110 located at the surface of the well system 26. This provides for a wireless communications link between the through tubing completion 48 and an operator located at the surface of the well.
Referring generally to FIG. 6, another embodiment of a through tubing completion system 20 is illustrated. The through tubing completion system illustrated in FIG. 6 may be similar to the through tubing completion system described with respect to FIG. 5. Therefore, in the interest of reducing the overall length of the disclosure, only the differences will be explained in detail.
In the embodiment illustrated in FIG. 6, the through tubing completion 48 may be located at a depth in which substantially wireless telemetry is either impractical or inefficient. To compensate for the depth, a series of short hop wireless telemetry modules 112 may be used. The short hop wireless telemetry modules 112 may include one or more anchors 114 to secure or fix the modules 112 to the existing upper completion 28/production tubing 30. In addition, the short hop wireless telemetry modules 112 may further include a length of production tubing 114, upper and lower wireless telemetry modules 112, and a cable 116 coupling the upper and lower wireless telemetry modules together. Although it is not shown in this figure, the short hope telemetry modules 112 also may include the power storage/generation module 102 to provide power to the various electrical components associated with the short hop wireless telemetry modules 112.
The short hop wireless telemetry modules 112 may be retrievable, similar to the retrievable communications module 96 coupled to the through tubing completion 48. The short hop modules 112 may communicate data, power, and other signals between the electric flow control valves 56, the sensors 58, and/or lower wireless telemetry module(s) of an adjacent short hop wireless telemetry module 112. These signals may be communicated to the upper wireless telemetry module 112 via cable 116. The upper wireless telemetry module 112 may then communicate data, power, and other signals to a wireless telemetry module 112 located at the surface. Because the transmissions between the corresponding wireless telemetry modules 112 are now over relatively shorter distances, the modules 112 themselves may be made smaller or of lower power than a system wirelessly transmitting to the surface from the through tubing completion 48.
As shown, in some embodiments, a break between corresponding wireless telemetry modules may occur at a location to allow the upper completion 28 to retain a previous capability. In the embodiment illustrated in FIG. 6, for example, there is a short hop wireless transmission across the SCSSV 32, allowing the SCSSV 32 to be able to close when needed. In addition, only one short hop wireless telemetry module is shown above the through tubing completion 48. However, two or more short hop wireless telemetry modules 112 may be used as needed. In some cases, standardized short hop wireless telemetry modules may replicated as many times as necessary to adequately cover the distance between the through tubing completion 48 and the wireless telemetry module 112 provided at the surface of the well system 26.
Referring generally to FIG. 7, another illustrative embodiment of the through tubing completion system 20 is illustrated. The through tubing completion system shown may be similar to the through tubing completion system described with respect to FIG. 5. Therefore, in the interest of reducing the overall length of the disclosure, only the differences will be explained in detail.
The retrievable wireless communications modules of FIGS. 5 and 6 are modified in the exemplary embodiment shown in FIG. 7. In this latter embodiment, the wireless telemetry module is replaced with a data writer 118, a plurality of recorder capsules 120, and a wireless signal receiver 122, where the wireless signal receiver 122 is suitable to receive a wireless signal selected from a pressure pulse inside the tubing sent from surface, a low frequency seismic/acoustic signal, an EM signal or a radio frequency type signal. As with the previous retrievable wireless communications modules, a downhole power storage/generator module, e.g. module 102, and a wet connect, such as one of the wet connect systems 21 described above, may be included to power and couple the retrievable wireless communications module to the top of the through tubing completion 48.
Data from the lateral bore 42 and other systems may be communicated from the sensors 58 provided in the through tubing completion 48 and recorded on a recorder capsule 120. A wireless low frequency seismic/acoustic signal may be sent from the surface to the wireless low frequency seismic/acoustic signal receiver 122. Alternately a pressure pulse in the fluid inside the tubing may be sent from surface to the pressure sensor 122. The information carried from the surface by the low frequency seismic/acoustic signal is used to set and control the electronic flow control valves 56 of the through tubing completion 48. In addition, the wireless low frequency seismic/acoustic signal receiver 122 may instruct a recorder capsule container 124 to release the recorder capsule 120 upon which the data has been written. The recorder capsule 120 may flow to the surface and provide a surface reader with information regarding the downhole environment and systems. In other embodiments, the recorder capsules 120 may be released at a predetermined time interval or upon another downhole event, such as the detection of water break through by one of the sensors. The recorder capsule system presents a lower cost alternative to the cost and expense of real time systems.
The retrievable wireless communications module may be replaced at predetermined intervals or upon an event, such as parameters indicating the end of life for the power storage module 102 or exhaustion of the supply of recorder capsules 120 from the recorder capsule container 124. During replacement, new recorder capsules 120 may be supplied for an additional time period of monitoring the downhole environment.
Referring in general to FIG. 8, another embodiment of the through tubing completion system 20 is illustrated. In this embodiment, system 20 comprises a wireless communications link 126. Wireless communications link 126 may be employed in a well system 26 having features, configurations, and components, which are the same or similar to many of the components described above with reference to the embodiments illustrated in FIGS. 1-7. As described above, for example, the well system 26 may comprise the existing upper completion 28 including completion components such as production tubing 30 and surface controlled subsurface safety valve (SCSSV) 32. The production tubing 30 and SCSSV 32 may be run in cased wellbore 34 having production casing 36. In the example shown, the annulus between the production tubing 30 and the production casing 36 may again be sealed with production packer 38.
When the well becomes depleted or begins to water out, the production deflector 40 may be run within the production tubing 30. The production deflector 40 facilitates a coil tubing or through tubing drilling operation to form the side track or lateral bore 42 to a new production location. After the lateral bore 42 is formed, the open lateral borehole is completed to control the flow of production fluid from the borehole. In some embodiments, the lateral borehole 42 may comprise more than one production zone 44, such as in a multi-zone wellbore.
To complete the lateral bore 42, the components of through bore completion 48 must again be able to pass through the smallest diameter of the existing upper completion 28. For example, the SCSSV 32 may restrict the outer diameter of the through tubing completion 48. The production tubing 50 of the through tubing completion 48 is sealed to the inner diameter of the existing production tubing 30 via ported packer 52. The ported packer 52 effectively seals the annulus between the production tubing 50 and the larger production tubing 30.
Included in this embodiment, the through tubing completion 48 similarly comprises a number of the electrically activated flow control valves (FCV) 56. The valves may be coupled with sensors 58 configured to measure and transmit one or more lateral borehole parameters, such as flow rate, pressure, temperature, water cut, resistivity, etc. The information may be transferred from (or to) the through tubing completion via the wireless communication link 126 coupled with cable 62. In addition, the cable 62 also may provide communication and/or power to individually control each of the downhole electric FCVs 56.
At an upper section of the smaller diameter production tubing 50 of the through tubing completion 48 illustrated in this embodiment, the wireless communication link 126 is provided to bridge a gap 128, such as a gap across the SCSSV 32. In this particular example, the gap 128 across the SCSSV 32 allows the safety valve of the existing upper completion 28 to still properly function in the event of some sort of well system failure. In the illustrated example, the gap 128 is selected to be on the order of 8 to 12 inches wide, which is sufficient to allow the SCSSV flapper to operate. When the SCSSV 32 is closed, communication may be restricted across this gap in some embodiments.
As illustrated, the wireless communication link 126 has a coil arrangement 130 having a coil 132 positioned generally at an upper section of the tubing 50 of the through tubing completion 48. A corresponding coil 134 of coil arrangement 130 is positioned across the gap 128. The coil arrangement 130 may be across the axis of the production tubing 50 or at an angle to the production tubing 50, as illustrated in the alternative coil arrangement of FIG. 9. In this embodiment, opening 54 is positioned just below the coil arrangement 130 to allow for the flow of production fluid around the coil arrangement 130 (within the annulus between the smaller diameter production tubing 50 and the larger production tubing 30).
The corresponding coil 134 of the coil arrangement 130 may be provided at the lower end of a section of production tubing 136 that extends to the surface. By way of example, production tubing 136 may have the same diameter as production tubing 50. An opening 138 may be provided through the sidewall of production tubing 136, similar to opening 54, just above the corresponding coil 134 so that production fluid may flow around the corresponding coil arrangement 130 (from the annulus within the larger production tubing 30 and back into the interior of the smaller diameter section of production tubing 136).
Both the coil 132 and corresponding coil 134 may be coupled by respective cables, such as cables 62 and 24. It should be noted that the coil 132 and the corresponding coil 134 each may be formed in a variety of coil arrangements and configurations utilizing individual or multiple coils. The coil 132 may be coupled by cable 62 to the electrical components of the through tubing completion 48 extending into the lateral bore hole 42, such as the electric flow control valves 56 and assorted sensors 58. The corresponding coil 134 may be coupled by cable 24 to a surface location for monitoring and/or control by an operator.
Referring generally to FIG. 10, another embodiment of a through tubing completion system 20 is illustrated. The through tubing completion system 20 shown may be similar to the through tubing completion system 20 described with respect to FIG. 8. Therefore, in the interest of reducing the overall length of the disclosure, only the differences will be explained in detail.
In the embodiment of FIG. 10, the coil arrangement 130 of the previous embodiment may be replaced with a toroidal coil arrangement 140. The toroidal coil arrangement 140 may be configured to function similar to the previously described coil arrangement 130. As shown in the figure, the toroidal coil arrangement 140 may be provided such that the flapper of an SCSSV 32 can continue to function as intended. A gap 128 of, for example, 8 to 12 inches is provided between corresponding toroidal coils 142, 144 of toroidal coil arrangement 140. In this example, the gap size is selected to allow the flapper to operate while still permitting a reasonable operative level of efficiency and effectiveness in transmitting power and/or communication signals between the toroidal coil arrangements. A cross-sectional view of one of the toroidal coils 142 or 144 is illustrated in FIG. 11. In this example, the toroidal coils 142, 144 are mounted to the upper end of production tubing 50 and to the lower end of production tubing section 136, respectively. The coil arrangement 130 or the toroidal coil arrangement 140 may be used to relay communication signals and/or power signals across 128.
Elements of the embodiments have been introduced with either the articles “a” or “an.” The articles are intended to mean that there are one or more of the elements. The terms “including” and “having” are intended to be inclusive such that there may be additional elements other than the elements listed. The term “or” when used with a list of at least two elements is intended to mean any element or combination of elements.
Although only a few embodiments of the present invention 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 invention. Accordingly, such modifications are intended to be included within the scope of this invention as defined in the claims.

Claims

1. A through tubing completion system run in a lateral borehole comprising:

a production tubing coupled to a flow control valve;

one or more sensors measuring at least one characteristic of the lateral borehole;

one of a male or female wet connect system configured to communicatively couple with the flow control valve and the one or more sensors;

wherein a corresponding one of the male or female wet connect system is placed in communication with the one of the male or female wet connect system in order to control the flow control valve and communicate the at least one characteristic of the lateral borehole.

2. The through tubing completion system of claim 1 in which the wet connect system is inductively coupled together.

3. The through tubing completion system of claim 1 in which the wet connect system comprises hydraulic and electrical components.

4. The through tubing completion system of claim 1 in which the flow control valves are electrically actuated.

5. The through tubing completion system of claim 1 in which the flow control valves are hydraulically actuated.

6. The through tubing completion system of claim 1 in which the corresponding one of a male or female wet connect system is included in a retrievable communications module retrievably coupled to an upper portion of the through tubing completion.

7. The through tubing completion system of claim 1, wherein the wet connect system is inductively coupled together at a location downhole and above the lateral borehole.

8. The through tubing completion system of claim 1, further comprising a short hop telemetry system to communicate the at least one characteristic of the lateral borehole uphole to a surface location.

9. The through tubing completion system of claim 2, wherein the wet connect system is inductively coupled together via a coil arrangement.

10. A method for installing a through tubing completion system comprising:

installing a production deflector in an existing completion;

drilling a lateral borehole;

running a through tubing completion comprising a flow control valve and one or more sensors through the existing completion;

coupling communication to a surface via a wet connect system.

11. The method of claim 10, wherein coupling communication comprises establishing the wet connect system with at least one of hydraulic and electrical components.

12. The method of claim 10, wherein coupling communication further comprises sending a retrievable communications module downhole to engage an upper portion of the through tubing completion.

13. The method of claim 10, wherein coupling communication comprises forming an inductive coupling to communicate data uphole from the one or more sensors.

14. The method of claim 13, wherein forming comprises utilizing a coil arrangement to communicate across a gap.

15. A through tubing completion system run in a lateral borehole comprising:

a production tubing coupled to a flow control valve;

a wireless communications module configured to wirelessly communicate with a surface location and coupled to an upper portion of the through tubing completion at a downhole location.

16. The through tubing completion system of claim 15, wherein the wireless communications module comprises a wireless telemetry module.

17. The through tubing completion system of claim 16, wherein the wireless telemetry module communicates with the surface location via one or more short hop wireless telemetry modules.

18. The through tubing completion system of claim 15, wherein the wireless communications module comprises a data writer, and a recordable capsule container releasably containing a plurality of recordable capsules;

wherein sensor data is recorded on one of the plurality of recordable capsules which is released to the surface.

19. The through tubing completion system of claim 15, wherein the wireless communications module comprises a coil arrangement to inductively communicate across a gap.

20. The through tubing completion system of claim 19, wherein the coil arrangement comprises a toroidal coil arrangement for communicating at least one of communication or power signals across the gap.