DOWNHOLE TOOL INCLUDING A LOWER COMPLETION COUPLED WITH A REMOTE MONITORING AND CONTROL MODULE

Abstract

Provided is a downhole tool, a well system, and a method. The downhole tool, in one aspect, includes a lower completion, and a half wet connect lower connection assembly coupled to an uphole end of the lower completion. The downhole tool, according to this aspect, further includes a remote monitoring and control module, and a half wet connect upper connection assembly coupled to a downhole end of the remote monitoring and control module, the half wet connect upper connection assembly and the half wet connect lower connection assembly coupled together to form a full wet connect assembly. In at least one aspect, the remote monitoring and control module is configured to perform a well test of a subterranean formation of a wellbore surrounding the lower completion prior to running an upper completion within the wellbore.

Description

CROSS-REFERENCE TO RELATED APPLICATION

This application claims the benefit of U.S. Provisional Application Ser. No. 63/494,083, filed on Apr. 4, 2023, entitled “INTELLIGENT COMPLETION DEPLOYMENT AND INSTALLATION WITH WELL TEST USING TELEMETRY AND INTELLIGENT WELL VALVES FOR EFFICIENCY IN OPERATIONS AND TEMPORARY WELL SUSPENSION” commonly assigned with this application and incorporated herein by reference in its entirety.

BACKGROUND

One key challenge for operators, especially in a subsea environment, is managing rig utilization to allow for drilling, completing, and testing a well, all the while meeting timelines for rig availability, construction of the subsea production system, laying of an umbilical, etc. In the scenario of well testing, typically, a well will be drilled, the lower and upper completions will be run, or a dedicated well test string will be run and then the well will be tested to determine relevant reservoir parameters and performance before handing the well over to the production teams.

BRIEF DESCRIPTION

Reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which:

FIG. 1 illustrates a well system designed, manufactured, and operated according to one or more embodiments of the disclosure; and

FIGS. 2 through 5 illustrate a well system designed, manufactured, and operated according to one or more embodiments of the disclosure at various different stages of completion.

DETAILED DESCRIPTION

In the drawings and descriptions that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawn figures are not necessarily to scale. Certain features of the disclosure may be shown exaggerated in scale or in somewhat schematic form and some details of certain elements may not be shown in the interest of clarity and conciseness. The present disclosure may be implemented in embodiments of different forms.

Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the disclosure, and is not intended to limit the disclosure to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.

Unless otherwise specified, use of the terms “connect,” “engage,” “couple,” “attach,” or any other like term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include an indirect interaction between the elements described.

Unless otherwise specified, use of the terms “up,” “upper,” “upward,” “uphole,” “upstream,” or other like terms shall be construed as generally away from the bottom, terminal end of a well, regardless of the wellbore orientation; likewise, use of the terms “down,” “lower,” “downward,” “downhole,” “downstream,” or other like terms shall be construed as generally toward the bottom, terminal end of a well, regardless of the wellbore orientation. Use of any one or more of the foregoing terms shall not be construed as denoting positions along a perfectly vertical axis. Unless otherwise specified, use of the term “subterranean formation” shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.

The present disclosure aims to provide operators the flexibility to deploy and install the lower section of an intelligent completion (e.g., lower completion) and then, in the same trip, perform a well test through intelligent completion interval control valves (ICVs) or lubricator valves (LVs) before running the upper completion and/or running a dedicated well test string. This offers the ability to test the well, isolate the lower completion through the ICV's, and then disconnect from the lower completion allowing for temporary suspension of the well, thus enabling efficient use of the rig during a failed campaign.

The present disclosure provides a downhole tool that includes three components (e.g., three primary components). The first component is a lower completion (e.g., an intelligent lower completion). The second component is an electrical and/or hydraulic and/or fiber optic wet connect tool coupled to the lower completion. The third component is a monitoring and control module (e.g., an acoustically activated remote monitoring and control module) coupled to the lower completion (e.g., through the wet connect assembly), which can operate the lower completion without the need for control lines being run back to surface.

The above components offer the ability for the downhole tool, including a lower completion of an intelligent well system to be run downhole on a downhole conveyance (e.g., on drill pipe) as an entire system, including packers, downhole sensors, fiber, and interval control valves (ICVs). Once at depth, a signal (e.g., acoustic signal) can be sent to the downhole tool (e.g., namely the remote monitoring and control module) to verify the integrity of the downhole tool and determine if any control lines were damaged while running the downhole tool to depth. Once the downhole tool is verified, the packers can be set, and the ICVs sequentially operated to commence clean-up and testing of the well. Through the remote monitoring and control module, the ICVs can be remotely functioned (e.g., manipulated) from surface, and pressures and temperatures can be monitored from each downhole sensor, and the resulting data transmitted acoustically back to surface. Once the well testing is complete, the ICVs can be commanded to close, isolating the reservoir. The downhole conveyance, remote monitoring and control module, and half wet connect upper connection assembly may then be retrieved back to the surface, leaving the half wet connect lower connection assembly and the lower completion in the wellbore. At this point, the operator has the option to run the upper completion and connect back into the lower completion (e.g., intelligent lower completion) or temporarily suspend the well (e.g., to enable efficient development of the field, among other reasons).

One key technical improvement of a downhole tool and well system according to the present disclosure is the ability to run the lower completion (e.g., intelligent lower completion) without control lines, and through the use of the remote monitoring and control module and the wet connect technology, monitor and control the lower completion. This improvement offers the operator the ability to perform a well test much earlier than is typically performed today, or suspend the well without the need to run the upper completion. This integrated solution has not been run in this type of configuration to date and specifically not for the purpose of early well testing or temporary suspension.

The above solution can allow the operator to perform a well test much earlier than is typically performed today, and reduces the number of trips into the well to perform this function. This capability also provides instant feedback as to reservoir conditions significantly earlier in a well construction process. This allows the operator improved insights before proceeding, potentially deciding not to run the upper completion and/or possibly the tree system and to move towards performing a stimulation treatment or even a sidetrack, or well abandonment, which can provide the capability to reduce overall CAPEX expenditure. In addition, this solution provides the operator significantly more flexibility in developing a field by allowing for temporary suspension of a well without the need to run the upper completion and or tree system until a later time that meets the rig and construction schedule. There are also benefits in performing a reservoir flow back/cleanup flow prior to suspending a well for extended periods. For many completions, this type of offering, allows for a revolutionary method to use advanced completion products in a manner that provides significant value to the customer in reducing rig time, ability to understand faster if a well is not a viable option, as well as the flexibility to offer additional opportunities for managing a complex field development schedule.

While the present disclosure may include many different steps for running a well system including a downhole tool, in at least one embodiment the steps to running the well system including the downhole tool may include: 1) The lower completion (e.g., the lower section of the intelligent lower completion) of the downhole tool would be made up on the rig floor, which involves termination of the electrical and/or hydraulic and/or fiber optic control lines of the lower completion at a half wet connect lower connection assembly; 2) The remote monitoring and control module of the downhole tool would be made up with an half wet connect upper connection assembly, which involves termination of the electrical and/or hydraulic and/or fiber optic control lines of the remote monitoring and control module at a half wet connect lower connection assembly; 3) The downhole conveyance (e.g., drill pipe, service string, or appropriate tubing) would be made up above the remote monitoring and control module; 4) The lower completion, remote monitoring and control module, and downhole conveyance would be coupled together, for example, using the half wet connect lower connection assembly coupled to the lower completion and the half wet connect upper connection assembly coupled to the remote monitoring and control module; 5) The downhole tool would be run on the downhole conveyance (e.g., drill pipe, service string, or appropriate tubing) to the predefined setting depth; 6) Once at depth, a signal (e.g., generated via a signal generator, such as a wireless acoustic module attached to the downhole conveyance at surface) would be sent through the downhole conveyance to the remote monitoring and control module at depth, allowing for the integrity of the control lines of the lower completion to be verified hydraulically and/or electrically and/or optically; 7) The ICVs of the lower completion can be commanded closed, if required; 8) The production packer of the lower completion can then be set from the surface (e.g., acoustically, hydraulically, etc. set from the surface), and in addition, the downhole sensor data can be monitored to ensure packer setting integrity; 9) The ICVs of the lower completion can then be commanded open and/or closed in any order after packer testing, allowing for a clean-up and/or well testing program to be executed, for example while having real time access to downhole conditions via the permanent downhole sensors and also insights into the ICV positions; 10) Upon completion of the well testing program, the ICVs can be commanded closed to isolate the reservoir; 11) The downhole conveyance, remote monitoring and control module, and half wet connect upper connection assembly may then be disconnected from the half wet connect lower connection assembly and the lower completion, and retrieved to the surface; and 12) The operator can then decide to run the upper completion downhole and engage with the lower completion, move towards stimulation and/or intervention, or alternatively temporarily suspend the completion.

In at least one embodiment, the remote monitoring and control module can be used to operate any electrically, optically or hydraulically connected devices.

In at least one other embodiment, the proposed solution provides a step change in how wells are completed and tested today. Using a well system in the proposed way allows companies to offer a differentiating service and product that has not been available to date. In addition, subsea development projects are costly, and thus having the capability to know sooner if a well is not performing as expected or having the flexibility to suspend a well without the need for running the upper completion or tree system is a significant benefit to the operators.

In at least one other embodiment, the remote monitoring and control module is an integrity checker, as might be obtained and purchased from Halliburton.

Turning to FIG. 1, illustrated is a well system 100 designed, manufactured and/or operated according to one or more embodiments of the disclosure. The well system 100 includes a platform 120 positioned over a subterranean formation 110 located below the earth's surface 115. The platform 120, in at least one embodiment, has a hoisting apparatus 125 and a derrick 130 for raising and lowering a downhole conveyance 140, such as a drill string, casing string, tubing string, coiled tubing, a running tool, etc. Although a land-based oil and gas platform 120 is illustrated in FIG. 1, the scope of this disclosure is not thereby limited, and thus could potentially apply to offshore applications. The teachings of this disclosure may also be applied to other land-based multilateral wells different from that illustrated.

The well system 100, in one or more embodiments, further includes a main wellbore 150. The main wellbore 150, in the illustrated embodiment, includes tubing 160, 165, which may have differing tubular diameters. Extending from the main wellbore 150, in one or more embodiments, may be one or more lateral wellbores 170. Furthermore, a plurality of multilateral junctions 175 may be positioned at junctions between the main wellbore 150 and the lateral wellbores 170. The multilateral junctions 175 may be designed, manufactured and operated according to one or more embodiments of the disclosure. The well system 100 may additionally include one or more ICVs 180 positioned at various locations within the main wellbore 150 and/or one or more of the lateral wellbores 170. The well system 100 may additionally include a control unit 190. The control unit 190, in this embodiment, is operable to provide control to, or receive signals from, one or more downhole devices.

FIGS. 2 through 5 illustrate a well system 200 designed, manufactured, and operated according to one or more alternative embodiments of the disclosure at various different stages of completion. The well system 200 may include a platform (not shown) positioned over a subterranean formation 210 located below the earth's surface. The platform, in at least one embodiment, has a hoisting apparatus and a derrick for raising and lowering a downhole conveyance 220, such as a workstring, service string, casing string, tubing string, coiled tubing, a running tool, etc. Although a land-based well system 200 is contemplated in FIG. 2, the scope of this disclosure is not thereby limited, and thus could potentially apply to offshore applications. The teachings of this disclosure may also be applied to other land-based wells different from that illustrated.

The well system 200, in one or more embodiments, further includes a wellbore 230 formed through the subterranean formation 210. The wellbore 230, in the illustrated embodiment, may include a lower completion 240 (e.g., intelligent lower completion). The lower completion 240, in accordance with one embodiment, may include one or more flow control devices 250 (e.g., interval control valves or ICVs) and/or one or more downhole sensors 255 (e.g., downhole gauges). In the illustrated embodiment, the one or more flow control devices 250 and/or one or more downhole sensors 255 are not physically coupled to the surface (e.g., via any control lines), but may be accessed wirelessly (e.g., acoustically) as will be discussed in greater detail below. The lower completion 240, in one or more additional embodiments, may further include one or more packers (e.g., an uphole feedthrough packer 260 and/or a downhole packer 265). The lower completion 240, in at least one embodiment, may further include a half wet connect lower connection assembly 270.

The lower completion 240, in the illustrated embodiment of FIG. 2, spans a single zone of interest. In yet other embodiments, the lower completion 240 could span multiple zones of interest, and thus could include multiple zones, each including their own downhole packer 265, one or more flow control devices 250, and one or more downhole sensors 255.

In accordance with one embodiment of the disclosure, a remote monitoring and control module 280 may be positioned uphole of the lower completion 240. For example, the remote monitoring and control module 280 may be placed between the downhole conveyance 220 and a half wet connect upper connection assembly 285 configured to engage with the wet connect lower connector assembly 270. In the illustrated embodiment, the half wet connect lower connection assembly 270 and the half wet connect upper connection assembly 285 engage one another to form a wet connect 290 assembly.

In at least one embodiment, the remote monitoring and control module 280 is configured to perform well tests of the wellbore 230 prior to running an upper completion within the wellbore 230. For example, the remote monitoring and control module 280, in at least one embodiment, is an acoustic/pulse telemetry device with monitoring and control capability for the lower completion 240 (e.g., intelligent well portion of the lower completion 240) via the half wet connect lower connection assembly 270 and the half wet connect upper connection assembly 285. In at least one embodiment, the remote monitoring and control module 280 may be obtained from Halliburton, Inc. under the Tradename Integrity Checker®.

FIG. 2 further illustrates that the downhole device 295, which may include the lower completion 240 (e.g., intelligent well portion of the lower completion 240), half wet connect lower connection assembly 270, half wet connect upper connection assembly 285, and remote monitoring and control module 280, is run on the downhole conveyance 220. Once at depth, the one or more control lines of the lower completion 240 may be checked using the remote monitoring and control module 280. If the one or more control lines check out, the uphole feedthrough packer 260 and/or the downhole packer 265 can then be set and the individual zonal flow control devices 250 opened remotely via a signal (e.g., telemetry signal, such as an acoustic signal) sent from surface via the downhole conveyance 220. The signal sent from surface may be converted to an electrical, hydraulic or fiber conduit via the half wet connect lower connection assembly 270 and half wet connect upper connection assembly 285 (e.g., full wet connect assembly 290). This will allow for monitoring and control of the lower completion 240, enabling remote well clean up and testing of the well system 200 without the need to run the upper completion and tubing hanger.

In at least one embodiment, the downhole device 295 includes one or more actuators for actuating one or more of the devices within the lower completion 240. For example, in at least one embodiment, the one or more actuators (e.g., flow control devices 250, downhole sensors 255, etc.) are one or more electric actuators, one or more hydro/electric actuators, one or more hydraulic actuators, or a combination of the foregoing. The one or more actuators, in at least one embodiment, are located in the remote monitoring and control module 280 of the downhole tool 295. In yet another embodiment, the one or more actuators are located in the lower completion 240 of the downhole tool 295, or both in the lower completion 240 and the remote monitoring and control module 280 of the downhole tool 295.

FIG. 3 illustrates that once the well cleanup is complete and/or zones flow tested, the flow control devices 250 can be closed, isolating the reservoir. The downhole conveyance 220, and remote monitoring and control module 280 and half wet connect upper connection assembly 285 of the downhole device 295 may then be retrieved to surface. The operator, for example based on reservoir performance, may decide to run the upper completion right away or temporarily suspend the well for a period of time.

FIG. 4 illustrates that once operator is ready, the upper completion 410 may be run in the wellbore 230, with another half wet connect upper connection assembly 485 coupled to a downhole end thereof. The upper completion may additionally include additional features, such as safety valves, chemical injection equipment, gas lift equipment, etc. . . . As discussed above, in at least one embodiment this is done with the reservoir still being isolated by the lower completion 240.

FIG. 5 illustrates that once the upper completion 410 is close to being on depth, the half wet connect upper connection assembly 485 is reconnected with the half wet connect lower connection assembly 270. Furthermore, a travel joint may allow further downward travel to allow for landing of a tubing hanger. The half wet connect upper connection assembly 485 is now connected with the half wet connect lower connection assembly 270, providing electrical, hydraulic and/or fiber optic connectivity and communication from surface via control lines, wired pipe conduits and/or wireless telemetry. In the illustrated embodiment, the half wet connect lower connection assembly 270 and the half wet connect upper connection assembly 485 engage one another to form a full wet connect assembly 590.

Aspects Disclosed Herein Include:

A. A downhole tool, the downhole tool including: 1) a lower completion; 2) a half wet connect lower connection assembly coupled to an uphole end of the lower completion; 3) a remote monitoring and control module; and 4) a half wet connect upper connection assembly coupled to a downhole end of the remote monitoring and control module, the half wet connect upper connection assembly and the half wet connect lower connection assembly coupled together to form a full wet connect assembly, and further when the remote monitoring and control module is configured to perform a well test of a subterranean formation of a wellbore surrounding the lower completion prior to running an upper completion within the wellbore.

B. A well system, the well system including: 1) a wellbore extending through one or more subterranean formations; and 2) a downhole tool located in the wellbore, the downhole tool including: a) a lower completion; b) a half wet connect lower connection assembly coupled to an uphole end of the lower completion; c) a remote monitoring and control module; and d) a half wet connect upper connection assembly coupled to a downhole end of the remote monitoring and control module, the half wet connect upper connection assembly and the half wet connect lower connection assembly coupled together to form a full wet connect assembly, and further when the remote monitoring and control module is configured to perform a well test of the subterranean formation prior to running an upper completion within the wellbore.

C. A method, the method including: 1) forming a wellbore through one or more subterranean formations; 2) positioning a downhole tool in the wellbore, the downhole tool including: a) a lower completion; b) a half wet connect lower connection assembly coupled to an uphole end of the lower completion; c) a remote monitoring and control module; and d) a half wet connect upper connection assembly coupled to a downhole end of the remote monitoring and control module, the half wet connect upper connection assembly and the half wet connect lower connection assembly coupled together to form a full wet connect assembly; and 3) performing a well test of the subterranean formation using the downhole tool.

Aspects A, B, and C may have one or more of the following additional elements in combination: Element 1: wherein the lower completion includes one or more flow control devices, the remote monitoring and control module configured to move at least one of the one or more flow control devices between closed and open positions and perform the well test. Element 2: wherein the one or more flow control devices are one or more active flow control devices. Element 3: wherein the lower completion includes one or more downhole sensors, the remote monitoring and control module configured to interface with the one or more downhole sensors and perform the well test. Element 4: wherein the lower completion includes one or more flow control devices and one or more downhole sensors, the remote monitoring and control module configured to move at least one of the one or more flow control devices between closed and open positions and interface with the one or more downhole sensors to perform the well test. Element 5: wherein the lower completion includes an uphole feedthrough packer and a downhole packer. Element 6: further including disconnecting the half wet connect upper connection assembly and attached remote monitoring and control module from the half wet connect lower connection assembly after performing the well test. Element 7: further including connecting a second half wet connect upper connection assembly having an upper completion coupled thereto with the half wet connect lower connection assembly and the lower completion after disconnecting the half wet connect upper connection assembly and attached remote monitoring and control module from the half wet connect lower connection assembly. Element 8: wherein the lower completion includes one or more flow control devices, the remote monitoring and control module configured to move at least one of the one or more flow control devices between closed and open positions and perform the well test. Element 9: wherein the one or more flow control devices are one or more active flow control devices. Element 10: wherein the performing includes performing one or more flow tests on the subterranean formation as the one or more flow control devices move between the closed and open positions. Element 11: wherein the lower completion includes one or more downhole sensors, the remote monitoring and control module configured to interface with the one or more downhole sensors and perform the well test. Element 12: wherein the performing includes performing one or more flow tests on the subterranean formation using the one or more downhole sensors. Element 13: wherein the lower completion includes one or more flow control devices and one or more downhole sensors, the remote monitoring and control module configured to move at least one of the one or more flow control devices between closed and open positions and interface with the one or more downhole sensors to perform the well test. Element 14: wherein performing the well test of the subterranean formation using the downhole tool includes performing the well test without any control lines extending from a surface of the wellbore to the lower completion.

Those skilled in the art to which this application relates will appreciate that other and further additions, deletions, substitutions and modifications may be made to the described embodiments.

Claims

1. A downhole tool, comprising:

a lower completion;

a half wet connect lower connection assembly coupled to an uphole end of the lower completion;

a remote monitoring and control module; and

a half wet connect upper connection assembly coupled to a downhole end of the remote monitoring and control module, the half wet connect upper connection assembly and the half wet connect lower connection assembly coupled together to form a full wet connect assembly, and further when the remote monitoring and control module is configured to perform a well test of a subterranean formation of a wellbore surrounding the lower completion prior to running an upper completion within the wellbore.

2. The downhole tool as recited in claim 1, wherein the lower completion includes one or more flow control devices, the remote monitoring and control module configured to move at least one of the one or more flow control devices between closed and open positions and perform the well test.

3. The downhole tool as recited in claim 2, wherein the one or more flow control devices are one or more active flow control devices.

4. The downhole tool as recited in claim 1, wherein the lower completion includes one or more downhole sensors, the remote monitoring and control module configured to interface with the one or more downhole sensors and perform the well test.

5. The downhole tool as recited in claim 1, wherein the lower completion includes one or more flow control devices and one or more downhole sensors, the remote monitoring and control module configured to move at least one of the one or more flow control devices between closed and open positions and interface with the one or more downhole sensors to perform the well test.

6. The downhole tool as recited in claim 1, wherein the lower completion includes an uphole feedthrough packer and a downhole packer.

7. A well system, comprising:

a wellbore extending through one or more subterranean formations; and

a downhole tool located in the wellbore, the downhole tool including: a lower completion; a half wet connect lower connection assembly coupled to an uphole end of the lower completion; a remote monitoring and control module; and a half wet connect upper connection assembly coupled to a downhole end of the remote monitoring and control module, the half wet connect upper connection assembly and the half wet connect lower connection assembly coupled together to form a full wet connect assembly, and further when the remote monitoring and control module is configured to perform a well test of the subterranean formation prior to running an upper completion within the wellbore.

8. The well system as recited in claim 7, wherein the lower completion includes one or more flow control devices, the remote monitoring and control module configured to move at least one of the one or more flow control devices between closed and open positions and perform the well test.

9. The well system as recited in claim 8, wherein the one or more flow control devices are one or more active flow control devices.

10. The well system as recited in claim 7, wherein the lower completion includes one or more downhole sensors, the remote monitoring and control module configured to interface with the one or more downhole sensors and perform the well test.

11. The well system as recited in claim 7, wherein the lower completion includes one or more flow control devices and one or more downhole sensors, the remote monitoring and control module configured to move at least one of the one or more flow control devices between closed and open positions and interface with the one or more downhole sensors to perform the well test.

12. The well system as recited in claim 7, wherein the lower completion includes an uphole feedthrough packer and a downhole packer.

13. A method, comprising:

forming a wellbore through one or more subterranean formations;

positioning a downhole tool in the wellbore, the downhole tool including: a lower completion; a half wet connect lower connection assembly coupled to an uphole end of the lower completion; a remote monitoring and control module; and a half wet connect upper connection assembly coupled to a downhole end of the remote monitoring and control module, the half wet connect upper connection assembly and the half wet connect lower connection assembly coupled together to form a full wet connect assembly; and

performing a well test of the subterranean formation using the downhole tool.

14. The method as recited in claim 13, further including disconnecting the half wet connect upper connection assembly and attached remote monitoring and control module from the half wet connect lower connection assembly after performing the well test.

15. The method as recited in claim 14, further including connecting a second half wet connect upper connection assembly having an upper completion coupled thereto with the half wet connect lower connection assembly and the lower completion after disconnecting the half wet connect upper connection assembly and attached remote monitoring and control module from the half wet connect lower connection assembly.

16. The method as recited in claim 13, wherein the lower completion includes one or more flow control devices, the remote monitoring and control module configured to move at least one of the one or more flow control devices between closed and open positions and perform the well test.

17. The method as recited in claim 16, wherein the one or more flow control devices are one or more active flow control devices.

18. The method as recited in claim 16, wherein the performing includes performing one or more flow tests on the subterranean formation as the one or more flow control devices move between the closed and open positions.

19. The method as recited in claim 13, wherein the lower completion includes one or more downhole sensors, the remote monitoring and control module configured to interface with the one or more downhole sensors and perform the well test.

20. The method as recited in claim 19, wherein the performing includes performing one or more flow tests on the subterranean formation using the one or more downhole sensors.

21. The method as recited in claim 13, wherein the lower completion includes one or more flow control devices and one or more downhole sensors, the remote monitoring and control module configured to move at least one of the one or more flow control devices between closed and open positions and interface with the one or more downhole sensors to perform the well test.

22. The method as recited in claim 13, wherein performing the well test of the subterranean formation using the downhole tool includes performing the well test without any control lines extending from a surface of the wellbore to the lower completion.