A method and system for providing application for wellbore schematic designing and managing well completion

Abstract

The present invention relates to a method (300) and system (100) for providing an application for wellbore schematic designing and managing wellbore completions. The method (300) is configured to display a user interface (UI) with a canvas and a well schematic library, allowing a user to position well components for wellbore design. Further, the method (300) generates the wellbore design based on user inputs and displays it on the UI. Further, simulation parameters are then received from the user, and the processor computes various well performance factors, such as tubing movement, particle size distribution, torque and drag, PVT analysis, and well barrier protection. Based on these computations, the system (100) determines necessary alterations to the wellbore design and applies these changes to optimize well completion. This method enables dynamic and efficient wellbore management, integrating design adjustments and simulations to ensure optimal performance and safety in well completion processes.

Description

[0001] TITLE OF INVENTION:

[0002] A METHOD AND SYSTEM FOR PROVIDING APPLICATION FOR WELLBORE SCHEMATIC DESIGNING AND MANAGING WELL COMPLETION

[0003] CROSS-REFERENCE TO RELATED APPLICATIONS AND PRIORITY The present application claims priority from the Indian patent application having application number 202521002164 filed on 09 January 2025, incorporated herein by a reference

[0004] TECHNICAL FIELD

[0005] The presently disclosed embodiments relate, in general, to wellbore design and management systems by performing wellbore calculations. More specifically, the invention pertains to systems for providing an application that assists in designing wellbore schematics and managing well completions, integrating various tools for simulation, calculation ,optimization, and monitoring of drilling and completion operations.

[0006] BACKGROUND

[0007] This section is intended to introduce the reader to various aspects of art, which may be related to various aspects of the present disclosure that are described or claimed below. This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure. Accordingly, it should be understood that these statements in this background section are to be read in this light, and not as admissions of prior art. Similarly, a problem mentioned in the background section or associated with the subject matter of the background section should not be assumed to have been previously recognized in the prior art. The subject matter in the background section merely represents different approaches, which in and of themselves may also correspond to implementations of the claimed technology.

[0008] In the era of oil and gas exploration, industry has relied heavily on complex technologies and methodologies to extract valuable resources from subsurface reservoirs. Wellbore design and completion are integral to this process, requiring a detailed understanding of the geological formations, the well trajectory, and the selection of various components such as casings, tubing, completions equipment, pumps, and valves. The planning and execution of these designs is crucial for ensuring the well's long-term structural integrity and operational efficiency. However, the traditionalapproaches to wellbore design and completion have evolved slowly, and engineers have long faced challenges in visualizing, calculating, monitoring and optimizing wellbore structures in real-time with precision and high accuracy. The complexity and risks associated with well completion operations often result in expensive delays, inefficiencies, and other operational risks.

[0009] Historically, the wellbore design and completion processes were carried out using standalone desktop applications and spreadsheets, which required significant manual input and often lacked integration between design, analysis, and calculation tools. Tubing moment calculations, for instance, are essential in determining the forces acting on the tubing during various operations and ensuring that the system can handle the stresses of well completion. These calculations typically required offline tools that failed to provide dynamic, real-time feedback during the design phase, resulting in a slower, error-prone process. Additionally, conducting particle size distribution (PSD) analysis for selection of a correct mesh size for sand screens was often done using separate, often cumbersome Excel-based tools, making it difficult to integrate the crucial data along with the overall design.

[0010] Furthermore, the wellbore design process has traditionally been complex and time-consuming due to the need to account for a variety of factors. These include the varying lengths of tubing due to the effects of tubing compression and elongation in the well, the total length variation i.e. compression and elongation during completion operations, and the forces exerted on the tubing and installed equipment due to applied surface pressures or conditions during performing various well operations. Such factors require engineers to consider multiple variables and perform extensive calculations, often without the benefit of real-time feedback, which increases non-productive time (NPT) and other operational risks. As such, engineers often face difficulties in achieving the ideal balance between wellbore design and performance, leading to inefficiencies in both the drilling and completion phases. The existing solutions in the market have very limited accessibility and also have failed to fully address the growing need for a unified, accessible platform that integrates wellbore schematic design, tubing movement calculations, and PSD analysis, etc. In many cases, these solutions remain fragmented, with engineers needing to switch between different software tools and platforms to complete a single task. This lack of integration in these software’s often result in delays, increased complexity, and a great potential for errors. Moreover, traditional desktop applications do not offer the flexibility to collaborate in real-time or to make immediate adjustments based on new data. As a result, engineers often struggle to optimize the design process and reduce the risks associated withwellbore completion.

[0011] As a result, the wellbore design and completion process remain fragmented, time-consuming, and prone to inefficiencies. Engineers struggle to optimize well design in a way that balances cost, performance, and safety, and the inability to make real-time adjustments based on changing conditions increases the risk of errors and delays. There is a significant gap in the market for a comprehensive, integrated online solution that can provide engineers with the tools they need to design, calculate, and optimize wellbore structures efficiently. This gap has prompted the need for more advanced and accessible solutions that streamline the design process, enhance real-time collaboration, and reduce operational risks.

[0012] In summary, conventional wellbore schematic design and completion systems face significant challenges in real-time design optimization, integrated calculation management, and performance feedback. These limitations hinder the accuracy of wellbore design, preparation of bottom hole assembly structures, prolong decision-making cycles, and increase operational risks. Addressing these issues through a unified, real-time, and data-driven approach to wellbore design and analysis is crucial for enhancing system efficiency, improving design accuracy, and supporting the safe and cost-effective completion of wells in complex and high-risk environments.

[0013] SUMMARY

[0014] This summary is provided to introduce concepts related to a method and system for providing an application for wellbore schematics and managing well completion by performing various calculations and the concepts are further described below in the detailed description. This summary is not intended to identify essential features of the claimed subject matter nor is it intended for use in determining or limiting the scope of the claimed subject matter.

[0015] According to an embodiment illustrated herein, a method for providing an application for wellbore schematic drawing and managing well completion operations by performing various calculations is disclosed. In one implementation of the present disclosure, the method may involve various steps performed by a processor coupled with an application server or a portable electronic device. The method may comprise a step of displaying a user interface (UI). Further, the user interface may comprise a canvas and a well schematic library comprising one or more well components. Further, the method may comprise a step of receiving one or more user inputs from a user to position the one or more well components on the canvas for designing the wellbore. Further, the method may comprisea step of generating a wellbore design using the one or more well components based on the received one or more inputs. Further, the method may comprise a step of displaying the wellbore design on the canvas of the UI. Further, the method may comprise a step of receiving a plurality of simulation parameters associated with the wellbore design from the user. Further, the method may comprise a step of computing at least one of a tubing movement calculation, a particle size distribution, a torque and drag,a PVT analysis, a well barrier for protection of the wellbore based on the received plurality of simulation parameters. Further, the method may comprise a step of determining one or more alterations to the wellbore design based on the computed at least one of the tubing movement calculations, the particle size distribution, the torque and drag,the PVT analysis, the well barrier for protection of the wellbore. Further, the method may comprise a step of performing the one or more alterations to the wellbore design for managing the well completion.

[0016] According to embodiments illustrated herein, there is provided a system to provide an application for wellbore schematic designing and managing well completion is disclosed. In one implementation of the present disclosure, the system may comprise the processor and a memory communicatively coupled with the processor. The memory may be configured to store one or more executable instructions, which causes the processor to perform various steps. The processor may be configured to display a user interface (UI). Further, the UI may comprise a canvas and a well schematic library that may comprise one or more well components. Further, the processor may be configured to receive one or more user inputs from a user to position the one or more well components on the canvas for designing the wellbore. Further, the processor may be configured to generate a wellbore design using the one or more well components based on the received one or more inputs. Further, the processor may be configured to display the wellbore design on the canvas of the UI. Further, the processor may be configured to receive a plurality of simulation parameters associated with the wellbore design from the user. Further, the processor may be configured to compute at least one of a tubing movement, a particle size distribution, a torque and drag a PVT analysis, a well barrier for protection of the wellbore based on the received plurality of simulation parameters. Further, the processor may be configured to determine one or more alterations to the wellbore design based on the computed at least one of the tubing movement, the particle size distribution, the torque and drag, a PVT Analysis, a Well barrier for protection of the wellbore. Furthermore, the processor may be configured to perform the one or more alterations to the wellbore design for managing the well completion.

[0017] The foregoing summary is illustrative and not intended to limit the scope of the claimed subject matter.In addition to the illustrative aspects, embodiments, and features will become apparent by reference to the detailed description and accompanying drawings.

[0018] BRIEF DESCRIPTION OF DRAWINGS

[0019] The accompanying drawings illustrate the various embodiments of systems, methods, and other aspects of the disclosure. Any person with ordinary skills in the art will appreciate that the illustrated element boundaries (e.g., boxes, groups of boxes, or other shapes) in the figures represent one example of the boundaries. In some examples, one element may be designed as multiple elements, or multiple elements may be designed as one element. In some examples, an element shown as an internal component of one element may be implemented as an external component in another, and vice versa. Further, the elements may not be drawn to scale.

[0020] Various embodiments will hereinafter be described in accordance with the appended drawings, which are provided to illustrate and not to limit the scope in any manner, wherein similar designations denote similar elements, and in which:

[0021] FIG. 1 is a block diagram that illustrates a system (100) for providing an application for wellbore schematic designing and managing well completion, in accordance with an embodiment of the present subject matter.

[0022] FIG. 2 is a block diagram that illustrates various components of an application server (104) configured for providing an application for wellbore schematic designing and managing well completion, in accordance with an embodiment of the present subject matter.

[0023] FIG. 3 is a flowchart that illustrates a method (300) for providing an application for wellbore schematic designing and managing well completion, in accordance with an embodiment of the present subject matter, and

[0024] FIG. 4 illustrates a block diagram (400) of an exemplary computer system for implementing embodiments consistent with the present subject matter.

[0025] DETAILED DESCRIPTION

[0026] The present disclosure may be best understood with reference to the detailed figures and description set forth herein. Various embodiments are discussed below with reference to the figures. However, those skilled in the art will readily appreciate that the detailed descriptions given herein with respect to the figures are simply for explanatory purposes as the methods and systems may extend beyond thedescribed embodiments. For example, the teachings presented, and the needs of a particular application may yield multiple alternative and suitable approaches to implement the functionality of any detail described herein. Therefore, any approach may extend beyond the particular implementation choices in the following embodiments described and shown.

[0027] References to “one embodiment,” “at least one embodiment,” “an embodiment,” “one example,” “an example,” “for example,” and so on indicate that the embodiment(s) or example(s) may include a particular feature, structure, characteristic, property, element, or limitation but that not every embodiment or example necessarily includes that particular feature, structure, characteristic, property, element, or limitation. Further, repeated use of the phrase “in an embodiment” does not necessarily refer to the same embodiment. The terms “comprise”, “comprising”, “include(s)”, or any other variations thereof, are intended to cover a non-exclusive inclusion, such that a setup, system or method that comprises a list of components or steps does not include only those components or steps but may include other components or steps not expressly listed or inherent to such setup or system or method. In other words, one or more elements in a system or apparatus preceded by “comprises... a” does not, without more constraints, preclude the existence of other elements or additional elements in the system or apparatus.

[0028] The objective of the present disclosure is to provide a secure environment for wellbore schematic designing and managing well completion, ensuring that all user data, design inputs, simulation parameters, and well completion details are encrypted and protected from unauthorized access. The system should implement industry-standard security protocols and access controls to safeguard sensitive information.

[0029] Another objective of the present disclosure is to offer an intuitive, user-friendly interface (UI) that allows users to easily design wellbores and manage well completion with minimal training. The UI should provide single click functionality, interactive fields, and tools for seamless interaction with the application, making the design process as simple and efficient as possible.

[0030] Another objective of the present disclosure is to enable real-time collaboration among multiple users within the UI, where users can concurrently perform operations for wellbore schematic designing and managing well completion. The system should support role-based access, allowing for different levels of privileges for editing and viewing the design.

[0031] Yet another objective of the present disclosure is to allow the system to dynamically calculate andadjust critical parameters, such as tubing movement, particle size distribution, torque and drag, and well barrier protection, based on user inputs and design modifications. The system should also provide machine learning techniques to optimize wellbore design in real time. Going forward the system may replicate the wellbore design based on past data base algorithms from the existing design created for a particular type of wells.

[0032] Yet another objective of the present disclosure is to provide an extensive well schematic stencil library with customizable templates for different well types (e.g., vertical, deviated, horizontal, multilateral wells, other well shapes ). The system should support easy, quick selection and modification of well components including casings, tubing, completions equipment, pumps, and valves, wellheads, packers, safety valves, sliding sleeve doors, sand screens, flow control equipment and more, based on the user’s specific design needs of that well.

[0033] Yet another objective of the present disclosure to support the integration of a wide range of simulation parameters (e.g., tubing pressure, annulus pressure, PVT analysis, fracture gradient) to perform in-depth analysis of the wellbore calculations. These parameters should include both static and dynamic conditions, such as temperature, fluid properties, and formation characteristics.

[0034] Yet another objective of the present disclosure is to enable the generation of both 2D and 3D representations of the wellbore design, which should be visually clear and informative. The system should allow users to view and alter the wellbore design in various formats, including schematic layers for different aspects of the design (e.g., surface equipment, downhole completion, production equipment).

[0035] Yet another objective of the present disclosure is to provide accurate simulations of well barrier integrity and protection, calculating the pressure exerted by fluid columns in both annulus and tubing and then comparing it with predefined threshold values to that of pore pressure. The system should alert users if any risk factors or weaknesses are detected in the wellbore design or completion as per the required industry standards.

[0036] Yet another objective of the present disclosure is to enable the application to be hosted on a cloudbased platform, allowing users to access the system remotely via a Software as a Service (SaaS) model. This should ensure scalability, flexibility, and ease of access, while also offering subscriptionbased pricing models for users based on their specific needs.Yet another objective of the present disclosure is to generate detailed reports of the wellbore design after alterations have been made, which include specifications, simulation results, and analysis data. These reports should be easily viewable by the user and exportable in various formats for further analysis, regulatory compliance, and stakeholder communication.

[0037] FIG. 1 is a block diagram that illustrates a system (100) to provide an application for wellbore schematic designing, preparing bottomhole assembly structures, and managing well completion by performing various calculations, in accordance with an embodiment of present subject matter. The system environment (100) typically includes a database server (102), an application server (104), a communication network (106), and one or more portable devices (108). The database server (102), the application server (104), and the one or more portable devices (108) are typically communicatively coupled with each other via the communication network (106). In an embodiment, the application server (104) may communicate with the database server (102), and one or more portable devices (108) using one or more protocols such as, but not limited to, Hypertext Transfer Protocol (HTTP), Transmission Control Protocol / Internet Protocol (TCP / IP), Wireless Application Protocol (WAP), RF mesh, Bluetooth Low Energy (BLE), and the like, to communicate with one another.

[0038] The database server (102) may refer to a computing device that may be configured to store executable instructions that enable the application server (104) to gather one or more user inputs from a user to position the one or more well components on a canvas for designing a wellbore, one or more well components, a plurality of simulation parameters, one or more alterations to the wellbore design, at least one of a tubing movement, a particle size distribution, a torque and drag, a PVT Analysis, a Well barrier for protection of the wellbore. Based on the user inputs and simulation metrics, the application server (104) processes this data to generate wellbore designs and suggest alterations. These alterations are derived from the analyzed metrics to ensure the wellbore design is optimized for performance, safety, and efficiency.

[0039] In an embodiment, the database server (102) may include a special purpose operating system specifically configured to perform one or more database operations related to wellbore schematic designing and managing well completion. Examples of database operations may include, but are not limited to, storing the one or more user inputs received from the user, storing the one or more well components on the canvas for designing the wellbore, but not limited to, the wellbore design on the canvas of the UI, the plurality of simulation parameters, one or more alterations. In an embodiment,the database server (102) may include hardware specifically configured to execute these operations, ensuring that application for wellbore schematic designing and managing well completion are handled efficiently and reliably. In another embodiment, the database server (102) may include hardware that may be configured to perform the wellbore schematic designing and the managing well completion. In an embodiment, the database server (102) may be realized through various technologies such as, but not limited to, Microsoft® SQL Server, Oracle®, IBM DB2®, Microsoft Access®, PostgreSQL®, MySQL®, SQLite®, AWS distributed database technology and the like. In an embodiment, the database server (102) may be configured to utilize the application server (104) for various operations that enhance the overall functionality of the system for providing application thereby optimizing the wellbore schematic designing and managing well completion.

[0040] A person with ordinary skills in art will understand that the scope of the disclosure is not limited to the database server (102) as a separate entity. In an embodiment, the functionalities of the database server (102) can be integrated into the application server (104) or into the one or more portable device (108).

[0041] In an embodiment, the application server (104) may refer to a computing device or a software framework hosting an application or a software service. In an embodiment, the application server (104) may be implemented to execute procedures such as, but not limited to, programs, routines, or scripts stored in one or more memories for supporting the hosted application or the software service. In an embodiment, the hosted application or the software service may be configured to perform one or more predetermined operations. The application server (104) may be realized through various types of application servers such as, but are not limited to, a Java application server, a. NET framework application server, a Base4 application server, a PHP framework application server, NodeJS, React JS, or any other application server framework.

[0042] In an exemplary embodiment, the application server (104) may provide the wellbore schematic designing and managing well completion and the simulations based on the one or more user inputs. Further, the application server (104) may interact with the database server (102) to store critical design data, such as user-selected well components, simulation parameters, and task progress details. Further, the data storage capability is essential for optimizing wellbore design and performance, as well as maintaining user preferences across multiple design sessions. Additionally, the application server (104) may employ data aggregation logic to gather performance metrics on various wellbore designparameters, such as tubing movement, torque and drag, a PVT analysis, and particle size distribution. Further, the application for the wellbore schematic designing, preparing bottomhole assemblies and managing well completion by performing various calculations being hosted on the application server (104). Further, the server may be a cloud platform. Further, the application may be accessible to the user on a subscription basis for a pre-defined monetary compensation.

[0043] In an embodiment, the communication network (106) may correspond to a communication medium through which the application server (104), the database server (102), and the one or more portable device (108) may communicate with each other. Such a communication may be performed in accordance with various wired and wireless communication protocols. Examples of such wired and wireless communication protocols include, but are not limited to, Transmission Control Protocol and Internet Protocol (TCP / IP), User Datagram Protocol (UDP), Hypertext Transfer Protocol (HTTP), Wireless Application Protocol (WAP), File Transfer Protocol (FTP), ZigBee, EDGE, infrared IR), IEEE 802.11, 802.16, 2G, 3G, 4G, 5G, 6G, 7G cellular communication protocols, and / or Bluetooth (BT) communication protocols. The communication network (106) may either be a dedicated network or a shared network. Further, the communication network (106) may include a variety of network devices, including routers, bridges, servers, computing devices, storage devices, and the like. The communication network (106) may include, but is not limited to, the Internet, intranet, a cloud network, a Wireless Fidelity (Wi-Fi) network, a Wireless Local Area Network (WLAN), a Local Area Network (LAN), a cable network, the wireless network, a telephone network (e.g., Analog, Digital, POTS, PSTN, ISDN, ds), a telephone line (POTS), a Metropolitan Area Network (MAN), an electronic positioning network, an X.25 network, an optical network (e.g., PON), a satellite network (e.g., VS AT), a packet-switched network, a circuit-switched network, a public network, a private network, and / or other wired or wireless communications network configured to carry data.

[0044] In an embodiment, the one or more portable devices (108) may refer to a computing device used by a user. The one or more portable devices (108) may comprise of one or more processors and one or more memory. The one or more memories may include computer readable code that may be executable by one or more processors to perform predetermined operations. In an embodiment, the one or more portable devices (108) may present a web user interface for facilitating user interaction within the environment using the application server (104). Example web user interfaces presented on the one or more portable devices (108) may display an interactive canvas for wellbore design, showing schematic representations of well components. These interfaces may provide users to position andmodify various components, view real-time calculations related to wellbore parameters (such as tubing movement and torque and drag), and access simulation results, thereby optimizing the design and management of well completions. The portable devices (108) may also display alerts, updates, and suggestions based on the computations, ensuring that the user can make informed decisions and adjustments to the wellbore design efficiently. Examples of the one or more portable devices (108) may include, but are not limited to, a personal computer, a laptop, a computer desktop, a personal digital assistant (PDA), a mobile device, a tablet, or any other computing device.

[0045] In an exemplary embodiment, the web user interface (UI) presented on the one or more portable devices (108) may display a variety of interactive elements designed to provide the application for wellbore schematic designing and managing well completion. The user interface (UI) may include various interactive elements, such as the canvas for displaying the wellbore designs and a well schematic library containing a selection of well components. The UI allows users to input their design specifications by selecting and positioning these well components onto the canvas for designing the wellbore. In an exemplary embodiment, the UI is designed to receive inputs from the user regarding the desired well components, including tubing, casings, wellhead, pumps, valves, completions equipment, and other essential elements. As the user makes selections, the UI dynamically generates a wellbore design that reflects the chosen components. Once the design is generated, it is displayed on the canvas for review and further modification. Additionally, the UI may include options for the user to input simulation parameters, such as tubing movement, particle size distribution, and other critical parameters. Based on these inputs, the application computes various design factors, including torque and drag, well barrier calculations, and PVT analysis, ensuring the wellbore design's integrity and efficiency. Real-time feedback, such as progress indicators and simulation results, is presented to the user on the UI, allowing them to monitor the performance of their design decisions. The UI may also display updated recommendations for design alterations based on the calculated parameters, enabling the user to optimize their wellbore design. Interactive elements like confirmation dialogues, dropdown menus, and buttons guide the user through the design process, ensuring they are fully informed of the choices being made before finalizing the well completion design. Examples of the portable devices that can support this web-based user interface include personal computers, laptops, desktop computers, mobile devices, tablets, I-pads, or any other devices capable of running the application and providing a responsive, interactive design experience. This ensures the user is fully informed before finalizing any transactions. Examples of the one or more portable devices (108) mayinclude, but are not limited to, personal computers, laptops, desktop computers, personal digital assistants (PDAs), mobile devices, tablets, or any other computing devices capable of supporting the web user interface.

[0046] The system (100) can be implemented using hardware, software, or a combination of both, which includes using where suitable, one or more computer programs, mobile applications, or “apps” by deploying either on-premises over the corresponding computing terminals or virtually over cloud infrastructure. The system (100) may include various micro-services or groups of independent computer programs which can act independently in collaboration with other micro-services. The system (100) may also interact with a third-party or external computer system. Internally, the system (100) may be the central processor of all requests for transactions by the various actors or users of the system. A critical attribute of the system (100) is that it can concurrently and instantly execute tasks in collaboration with other systems.

[0047] FIG. 2 illustrates a block diagram illustrating various components of the application server (104) configured for providing the application for wellbore schematic designing and managing well completion, in accordance with an embodiment of the present subject matter. Further, FIG. 2 is explained in conjunction with elements from FIG. 1. Here, the application server (104) preferably includes a processor (202), a memory (204), a transceiver (206), an Input / Output unit (208), a User Interface unit (210), a designing unit (212), a computing unit (214), a display unit (216), and a report generation unit (218). The processor (202) is further preferably communicatively coupled to the memory (204), the transceiver (206), the Input / Output unit (208), the User Interface unit (210), the designing unit (212), the computing unit (214), the display unit (216), and the report generation unit (218), while the transceiver (206) is preferably communicatively coupled to the communication network (106).

[0048] The processor (202) comprises suitable logic, circuitry, interfaces, and / or code that may be configured to execute a set of instructions stored in the memory (204), and may be implemented based on several processor technologies known in the art. The processor (202) works in coordination with the transceiver (206), the Input / Output unit (208), the User Interface unit (210), the designing unit (212), the computing unit (214), the display unit (216), and the report generation unit (218) for providing the application for wellbore schematic designing and managing well completion. Examples of the processor (202) include, but not limited to, standard microprocessor, microcontroller, centralprocessing unit (CPU), an X86-based processor, a Reduced Instruction Set Computing (RISC) processor, an Application- Specific Integrated Circuit (ASIC) processor, and a Complex Instruction Set Computing (CISC) processor, distributed or cloud processing unit, state machines, logic circuitries, and / or any devices that manipulate signals based on operational instructions and / or other processing logic that accommodates the requirements of the present invention.

[0049] The memory (204) comprises suitable logic, circuitry, interfaces, and / or code that may be configured to store the set of instructions, which are executed by the processor (202). Preferably, the memory (204) is configured to store one or more programs, routines, or scripts that are executed in coordination with the processor (202). Additionally, the memory (204) may include any computer-readable medium or computer program product known in the art including, for example, volatile memory, such as static random-access memory (SRAM) and dynamic random-access memory (DRAM), and / or nonvolatile memory, such as read only memory (ROM), erasable programmable ROM, a Hard Disk Drive (HDD), flash memories, Secure Digital (SD) card, Solid State Disks (SSD), optical disks, magnetic tapes, memory cards, virtual memory and distributed cloud storage. The memory (204) may be removable, non-removable, or a combination thereof. Further, the memory (204) may include routines, programs, objects, components, data structures, etc., which perform particular tasks or implement particular abstract data types. The memory (204) may include programs or coded instructions that supplement the applications and functions of the system (100). In one embodiment, the memory (204), amongst other things, serves as a repository for storing data processed, received, and generated by one or more of the programs or the coded instructions. In yet another embodiment, the memory (204) may be managed under a federated structure that enables the adaptability and responsiveness of the application server (104).

[0050] The transceiver (206) comprises suitable logic, circuitry, interfaces, and / or code that may be configured to receive, process or transmit information, data or signals, which are stored by the memory (204) and executed by the processor (202). The transceiver (206) is preferably configured to receive, process or transmit, one or more programs, routines, or scripts that are executed in coordination with the processor (202). The transceiver (206) is preferably communicatively coupled to the communication network (106) of the system (100) for communicating all the information, data, signal, programs, routines or scripts through the network.

[0051] The transceiver (206) may implement one or more known technologies to support wired or wirelesscommunication with the communication network (106). In an embodiment, the transceiver (206) may include but is not limited to, an antenna, a radio frequency (RF) transceiver, one or more amplifiers, a tuner, one or more oscillators, a digital signal processor, a Universal Serial Bus (USB) device, a coder-decoder (CODEC) chipset, a subscriber identity module (SIM) card, and / or a local buffer. Also, the transceiver (206) may communicate via wireless communication with networks, such as the Internet, an Intranet and / or a wireless network, such as a cellular telephone network, a wireless local area network (LAN) and / or a metropolitan area network (MAN). Accordingly, the wireless communication may use any of a plurality of communication standards, protocols and technologies, such as: Global System for Mobile Communications (GSM), Enhanced Data GSM Environment (EDGE), wideband code division multiple access (W-CDMA), code division multiple access (CDMA), time division multiple access (TDMA), Bluetooth, Wireless Fidelity (Wi-Fi) (e.g., IEEE 802.11a, IEEE 802.11b, IEEE 802.11g and / or IEEE 802.1 In), voice over Internet Protocol (VoIP), Wi-MAX, a protocol for email, instant messaging, and / or Short Message Service (SMS).

[0052] The input / output (I / O) unit (208) comprises suitable logic, circuitry, interfaces, and / or code that may be configured to receive or present information. The input / output unit (208) comprises various input and output devices that are configured to communicate with the processor (202). Examples of the input devices include, but are not limited to, a keyboard, a mouse, a joystick, a touch screen, a microphone, a camera, and / or a docking station. Examples of the output devices include, but are not limited to, a display screen and / or a speaker. The I / O unit (208) may include a variety of software and hardware interfaces, for example, a web interface, a graphical user interface, and the like. The I / O unit (208) may allow the system (100) to interact with the user directly or through the portable devices (108). Further, the I / O unit (208) may enable the system (100) to communicate with other computing devices, such as web servers and external data servers (not shown). The I / O unit (208) can facilitate multiple communications within a wide variety of networks and protocol types, including wired networks, for example, LAN, cable, etc., and wireless networks, such as WLAN, cellular, or satellite. The I / O unit (208) may include one or more ports for connecting a number of devices to one another or to another server. In one embodiment, the I / O unit (208) allows the application server (104) to be logically coupled to other portable devices (108), some of which may be built in. Illustrative components include tablets, mobile phones, desktop computers, wireless devices, etc.

[0053] In one embodiment, the input / output unit (208) may be configured to provide a seamless interaction interface between the user and the system (100). Further, the input / output unit (208) may beresponsible for displaying the user interface (UI). Further, the input / output unit (208) may be configured for receiving the one or more inputs from the user to position the one or more well components on the canvas for designing the wellbore. Further, the one or more inputs may comprise at least one of a single click input, a drag-and-drop point, a click input, a mouse hover, a touch input, wherein the one or more well components being positioned on the canvas using the single click input. Further, the input / output unit (208) may be configured to receive the plurality of simulation parameters associated with the wellbore design from the user. Further, the plurality of simulation parameters associated with the tubing movement may comprises material of pipe, Initial Tubing Pressure Ptlin psi (pounds per square inch), Final tubing pressure Pl2in psi (pounds per square inch), Initial Annulus Pressure PO1in psi (pounds per square inch), Final Annulus Pressure Po2in psi (pounds per square inch), Packer setting depth h in feet, Tubing fluid initial pL1in PPG (pounds per gallon ) or SG (specific gravity), Tubing fluid final pi2in PPG (pounds per gallon ) or SG (specific gravity), Annular fluid initial p01in PPG (pounds per gallon ) or SG (specific gravity), Annular fluid final po2in PPG (pounds per gallon ) or SG (specific gravity), Young’s Modulus E (pounds per square inch), Weight of Tubing in PPF (pounds per feet), Surface temperature Tsin degree Celsius (°C), Bottom Hole temperature Tbhin degree Celsius (°C), Geothermal Gradient, Thermal expansion coefficient a, Tubing ID in inches, Tubing OD in inches, Casing ID in inches, Seal Bore packer ID in inches, Length of Tubing L in feet, perforation depth in feet, and Fracture gradient psi / ft. Further, the plurality of simulation parameters associated with the torque and drag of the wellbore may comprises wellbore geometry, drilling fluid properties, drilling string configuration, rotational speed, bit weight, friction coefficients, and formation characteristics.

[0054] In another embodiment, the input / output unit (208) may be configured to receive one or more design modifications to the wellbore design from the user. Further, the input / output unit (208) may be configured to dynamically calculate and adjust the tubing movement calculations, the particle size distribution, the torque and drag, a PVT Analysis, a Well barrier for protection of the wellbore based on the one or more design modifications using one or more machine learning techniques.

[0055] In one embodiment, the user interface unit (210) of the application server (104) is disclosed. The user interface unit (210) may be configured to present the canvas and the well schematic library. Further, the user interface unit (210) may be configured to display the well design on the canvas of the UI. Further, the well schematic library comprising one or more well components. Further, the one or morewell components may comprises at least one of a wellheads, casing, tubing’s, safety valves, chemical injection mandrels and ports, packers, sliding sleeve, landing nipples, downhole valves and chokes, tubing plugs, sand screens, flow control valves, liner hangers, bridge plugs, cement and sand plugs, shoe and all other well completion components. Further, the one or more well components correspond to one or more templates designed and stored in the well schematic library, wherein the one or more templates on the canvas are pre-loaded for at least one of a vertical wells, deviated wells, horizontal wells, multilateral wells, other shaped wells for customization based on pre-defined well design conditions. Further, the UI may be configured to provide one or more interactive tools to enable the user for dynamically positioning the one or more well components within the canvas.

[0056] In an exemplary embodiment, the user interface unit (210) of the application server (104) may be configured to assist the users for creating the well completion designs starting from the schematic representation of the well to the final technical output. Further, the user interface unit (210) may allow the users to draw the well schematic and visually represent the installation of completion tools within the well. Further, the input data may be specific to the well such as type of information, chosen completion methods, the corresponding serial numbers for the equipment being utilized, and a combination thereof.

[0057] In another embodiment, the user interface unit (210) of the application server (104) may comprise one or more interactive fields to capture a first information associated with a customer and a second information associated with the wellbore design. Further, the first information associated with the customer may correspond to customer name, customer number, customer email, prepared for phone number, prepared for email, prepared by name, prepared by phone number, prepared by email, approved by name, approved by phone number, approved by email ID, date of preparation, and a combination thereof. Further, the second information associated with user may corresponds to the one or more parameters. Further, the one or more parameters may comprise a rig name, field name, well number, pad number, slot number, type of well, open hole size, completion fluid type, well name, liner, location of the well, and a combination thereof. Further, the well parameters may comprise a number of casings, size of casing. Further, a casing data may correspond to a type, a size OD in inches, weights, ID in inches, grade, drift ID in inches, grade, depth in feet, and a combination thereof. In yet another embodiment, the well parameters may comprise a CO2, H2S, deviation, final MD, water depth, gas oil ratio, oil water contact, gas oil contact, dog leg severity, bottom hole temperature (Deg°C / Deg°F) (BHT), Bottom hole Pressure (Psi)(BHP), RKB Elevation(m), Porosity, Saturation,Casing shoe depth (m), Perforation Depth / Depths in case of multiple perforations (in meters), Formation Type, Permeability, Formation Fluid, Density, Completion Fluid, Type of formation fluid, or a combination thereof.

[0058] In another embodiment, the user interface unit (210) may be configured provide a collaborative environment within the UI to a plurality of users where in real-time the plurality of user concurrently performs operations for wellbore schematic designing and managing well completion. Further, the plurality of users may be provided with role-based access for different levels of editing and viewing privileges.

[0059] In one embodiment, the designing unit (212) of the application server (104) is disclosed. The designing unit (212) may be configured to generate a wellbore design using the one or more well components based on the received one or more inputs. Further, the designing unit (212) of the application server (104) may comprise automatically or manually positioning on the canvas a first well component with respect to a second well component based on a working relation associated with each of the first well component and the second well component. Further, the canvas within the UI may be configured to provide a snap-to-grid functionality by enabling the one or more well components to align automatically or manually with predefined lines for precise placement. Further, the designing unit (212) may organize a plurality of schematic layers for different aspects of wellbore design, wherein the plurality of schematic layers corresponds to at least one of surface equipment, downhole completion, or production equipment.

[0060] In one embodiment, the computing unit (214) of the application server (104) is disclosed. The computing unit (214) may be configured to compute at least one of a tubing movement, a particle size distribution, a torque and drag,a PVT Analysis, a Well barrier for protection of the wellbore based on the received plurality of simulation parameters. Further, the tubing movement may be computed based on a Piston Effect, a Bucking Effect, a Ballooning Effect, a Temperature Effect, a Packer set Effect. Further, each of the Piston Effect, the Bucking Effect, the Ballooning Effect, the Temperature Effect, the Packer set Effect may be computed based on the plurality of simulation parameters associated with the tubing movement. Further, the tubing movement may be configured to design with considerations of various criteria related to drilling and completing the well, with tubing movement calculations ensuring the selection of the right equipment for installation, production, and other operations. Further, the calculations may predict the changes in the tubing’s physical parameters (such as length)due to environmental factors and loading conditions, enabling operators to plan mitigation actions and improving operational safety and efficiency. Further, the tubing moment calculation module may be configured to determine the force required to counteract elongation or contraction during completion installation or during the operations, using robust formulas to perform complex calculations and display results quickly and accurately. Further, the computing unit (214) mat be automatically calculates the tubing moments by inputting predefined parameters, streamlining operations and reducing human error.

[0061] Further, the computing unit (214) may be configured to receive a PSD input for at least one or more samples associated with a type of sand for sand screen selection of the wellbore completion from the user corresponding to number of sieves, opening of the sieves and soil retained when the sieve analysis is performed. Various different sizes of sieves are available for user to select and analysis is conducted on the instrument in laboratory. Further, the computing unit (214) may be configured to determine an Accumulative Retain percentage, a Mass Retain percentage, a Sand Passing percentage based on the received PSD input. Further, the computing unit (214) may be configured to compute at least one of a particle size distribution, Uniformity coefficient (Uc), a sorting coefficient (Sc), gravel percentage, fines percentage, and sand percentage based on the Accumulative Retain, the Mass Retain, and the Sand Passing. Further, the computing unit (214) may be configured to sort the one or more received samples through a process called Sand Sieve Analysis as a result of which the PSD curve which may represent as a log-normal curve is generated for one or multiple samples together. Further, the computing unit (214) may be configured to identify and recommend the user the possible options to eliminate the sand production scenario.

[0062] This allows the user to appropriately select the Sand screen (filter) to stop production of such sand as it possesses equipment erosion possibilities leading to failures.

[0063] In another embodiment, the computing unit (214) may be configured to define a screen size that may be suitable for the wellbore completion for the type of sand based on the computation. Further, the computing unit (214) may comprise the torque and drag of the wellbore being computed at least one of a mathematical model or computational algorithm that takes into account the real-time dynamics of the drilling or completions operation, including axial forces, rotational forces, torsional forces, and frictional losses between the drill string or completion string and wellbore walls or open hole. Further, the computing unit (214) may be configured to compute a plurality of parameters associated with thesecond barrier based on the the information of the second barrier, wherein the second barrier corresponds to the Casing,, liner, shear ram, intermediate casing, Subsurface Safety Valve, Packers, Flow Control Valves, wherein the information of the second barrier comprises casing size ID and OD, tubing size ID and OD, perforation depth, and reservoir pressure.

[0064] In one embodiment, the display unit (216) of the application server (104) is disclosed. The display unit (214) unit may be configured to determine one or more alterations to the wellbore design based on the computed at least one of the tubing movement, the particle size distribution, the torque and drag the, PVT analysis, the well barrier for protection of the wellbore. Further, the display unit (216) may be configured perform the one or more alterations to the wellbore design for managing the well completion. Further, the one or more alterations may comprise at least one of adjusting, scaling, repositioning the wellbore design and the one or more well components. Further, the display unit (216) may comprises recommending the one or more alterations to the wellbore design based on predefined simulation models, historical data, and best practices derived from previous well completion designs. Further, the display unit (216) may be configured to generate a 2D representation or 3D representation of the wellbore design comprising the one or more well components and displaying the 2D representation or the 3D representation on a display device of an electronic device of the user.

[0065] In another embodiment, the display unit (216) may be configured to receive a barrier input from the user via the UI. Further, the barrier input may correspond to information of a first barrier and a second barrier associated with the generated wellbore design. Further, the information of the first barrier may comprise a well fluid column, casing size ID and OD, tubing size ID and OD, perforation depth, reservoir pressure and temperature, Cement. Further, the display unit (216) may be configured to calculate a pressure exerted by the fluid column in the first barrier based on the information of the first barrier, a density of fluid, an acceleration due to gravity, and a perforation depth. Further, the display unit (216) may be configured to compare the calculated volume with a pre-defined threshold associated with a pore pressure. Further, the display unit (216) may be configured to provide an alert to the user if the calculated pressure is less than the pre-defined threshold associated with the pore pressure.

[0066] In one embodiment, the report generation unit (218) of the application server (104) is disclosed. The report generation unit (218) may be configured to generate a report of the wellbore design after performing the one or more alterations. Further, the report generation unit (218) may be configuredto display the generated report to the user. Further, the report may comprise a design data that may be associated with the wellbore design, one or more well component specifications, tubing parameters, PSD analysis results, or a combination thereof. Further, the report may be available in editable formats such as Excel or Word, or as a PDF, etc, depending on the user's preference. Further, the final report may correspond to the serialized numbers for each component, along with detailed descriptions and annotations that highlight the specific parts or sectors within the well, or a combination thereof. In an exemplary embodiment, the tubing movement calculation may comprise the following steps, wherein the user may select the type of the material from one or more types provided by the application from a dropdown UI. Further, the dropdown may correspond to Material of pipe (drop down will have material types) Initial Tubing Pressure Ptlin psi (pounds per square inch), Final tubing pressure Pi2in psi (pounds per square inch), Initial Annulus Pressure P01in psi (pounds per square inch), Final Annulus Pressure Po2in psi (pounds per square inch), Packer setting depth h in feet, Tubing fluid initial pL1in PPG (pounds per gallon) or SG (specific gravity), Tubing fluid final pL2in PPG (pounds per gallon) or SG (specific gravity), Annular fluid initial p01in PPG (pounds per gallon) or SG (specific gravity), Annular fluid final po2in PPG (pounds per gallon) or SG (specific gravity), Youngs Modulus E, Weight of tubing PPF in (pounds per feet), Surface temperature Tsin (°Deg C or °Deg F), Bottom Hole temperature Tbhin (°Deg C or °Deg F), Geothermal Gradient, Thermal expansion coefficient a, Tubing ID in inches, Tubing OD in inches, Casing ID in inches, Seal Bore packer ID in inches, Length of Tubing L in feet, perforation depth or depths in case of multiple perforations in meters, Fracture gradient.

[0067] Further, based on the above parameters the application may be configured to calculate the derived parameters such as:

[0068] a. Pii using the formula to calculate initial tubing pressure,

[0069] b. Pi2using the formula to calculate final tubing pressure,

[0070] c. dP(using the formula (P(1— Pl2) to calculate difference in initial and final tubing pressure, d. W to calculate the weight of fluid column inside the tubing in pounds per inch, e. Woto calculate the weight of fluid column inside the annulus in pounds per inch f. Wsis the weight of tubing in pounds per inch

[0071] g. Inertia I,

[0072] h. Ratio of Tubing OD / ID,i. Aj using formula to calculate area of tubing using tubing ID in inch square.,

[0073] j. Asusing formula to calculate cross-section area of tubing wall in inch square.

[0074] k. Apusing formula to calculate area of packer bore in inch square.,

[0075] l. R, Ratio of tubing Outer Diameter to Inner Diameter.

[0076] In the parameters,

[0077] • Vkj to calculate the weight of fluid column inside the tubing in pounds per inch, • Woto calculate the weight of fluid column inside the annulus in pounds per inch • Wsis the weight of tubing in pounds per inch

[0078] • AT is the total temperature change,

[0079] • a is the thermal expansion coefficient,

[0080] • ALis the tubing ID area in inch square,

[0081] • Aois the tubing OD area in inch square,

[0082] • Asis the area of tubing wall in inch square.,

[0083] • Apis the packer seal bore area in inch square,

[0084] • L is the length of tubing in feet,

[0085] • E is the Young’s modulus of elasticity,

[0086] • R Ratio of tubing Outer Diameter to Inner Diameter.,

[0087] 1. All the pressure parameters taken are in psi, all the length are taken in feet and area in inch square.

[0088] 2. p (rho) is the symbol used to denote the density.

[0089] 3. The tubing moment is calculated using the following 4 movements which are calculated independently.

[0090] • Piston Effect,

[0091] • Buckling Effect,

[0092] • Ballooning Effect,

[0093] • Temperature Effect,

[0094] using the formulas that are predefined in the system.

[0095] • The force applied for piston effect is denoted by Ft,

[0096] • The force applied for buckling effect is denoted by F2,• The force applied for ballooning effect is denoted by F3,

[0097] • The force applied for temperature effect is denoted by F4,

[0098] • The length change due to piston effect is denoted by 4 L4

[0099] • The length change due to buckling effect is denoted by A L2

[0100] • The length change due to ballooning effect is denoted by A L3

[0101] • The length change due to temperature effect is denoted by A L4

[0102] • Total length change due to all four length change effects is denoted by AL

[0103] • Total force change due to all four force effects is denoted by AF

[0104] • The software then calculates the total force to be slack off at the surface so as to counteract the upward movement in the subsurface tubing and displays the total force and length change along with individual forces and length change due to various effects Further, to calculate the input, derived quantities, final output calculations and final output for the tubing movement the system (100) comprise the following steps:

[0105] Further, the user defined parameters may correspond to:

[0106] a. Select Material for Pipe from the predefined catalogue- b. Enter Initial Tubing Pressure Pi4in psi

[0107] c. Enter Final Tubing Pressure Pi2in psi

[0108] d. Enter Initial Annulus Pressure PO1in psi

[0109] e. Enter Final Annulus Pressure Po2in psi

[0110] f. Enter Packer Setting Depth h in feet

[0111] g. Enter Initial Tubing Fluid density pL1in ppg

[0112] h. Enter Final Tubing Fluid density;2in ppg

[0113] i. Enter Initial Annulus Fluid density p01in ppg

[0114] j. Enter Final Annulus Fluid density po2in ppg

[0115] k. From API, Young’s modulus for steel pipe - Young’s modulus, E = 30000000 psi

[0116] l. Enter weight of tubing in Pounds per feet (PPF)

[0117] m. Enter Surface temperature Tsin °C or °F

[0118] n. Enter Bottom Hole temperature Tbhin °C or ° F

[0119] o. Enter geothermal gradient

[0120] p. Enter thermal expansion coefficient aq. Enter Tubing internal diameter ID in inches

[0121] r. Enter Tubing outer diameter OD in inches

[0122] s. Enter seal bore packer Internal Diameter in inches

[0123] t. Enter length of tubing in feet

[0124] u. Enter casing ID in inches

[0125] v. Enter the fracture gradient in psi / feet

[0126] w. Enter perforation depth or depths in feet

[0127] In another non-limiting embodiment, the system (100) may use the following formulas to derive quantities as follows:

[0128] Pil(at packer) ~ Pil d" (0.052 X pL1X / l) (1)

[0129] where(1is initial tubing fluid density

[0130] 2- Pi2(at packer) ~ Pi2 d" (0.052 X pl2X / l) (2)

[0131] where pi2is final tubing fluid density

[0132]

[0133] Pol (at packer) ~ Pol d" (0.052 X polX / l) (3)

[0134] where01is initial annulus fluid density

[0135] - Po2(at packer) Po2 T (0.052 X po2X / l) (4)

[0136] where po2is final annulus fluid density

[0137] 5. AP(= Pil-Pi2-- (5)

[0138] 6. AP0= Pol~Po2— - (6)

[0139] 7. Tubing fluid weight Wf = 0.0034 x pi2x Tubing ID

[0140] 8. Annulus fluid weight Wo= 0.0034 x po2x Tubing OD

[0141] , „T. „.. (Tubing OD)4- (Tubing ID)4

[0142] 9. Moment of Inertia I = 3.14 X - - — — - - — - 64

[0143] > Temperature at bottom hole+temprature at surf ace > (Tbh+Ts)

[0144] 10- Iavl - ~2~2

[0145] „ > Temperature at bottom hole+temprature at bottom hole _ ( Tbh+Tbh)

[0146] 1 1 - Iav2 -2 2

[0147] 19 AT _ Ttvi + I'av2

[0148] 1avg 2

[0149] . „ >. „.. >_T_ > Tubing OD

[0150] 13. Ratio of tubing OD to ID, R = -

[0151]

[0152] 14. Tubing ID area At = - (Tubing ID)

[0153] 42

[0154] 15. Tubing OD area Ao= (Tubing OD)2

[0155] 16. Cross section area of tubing As= - ((Tubing OD)2— (Tubing ID)2)

[0156] 4

[0157] 17. Packer Seal bore ID area Ap= (Seal Bore ID)2

[0158] _ Casing ID-Tubing OD

[0159] 18. Radius of casing clearance,

[0160]

[0161] 2

[0162] 19. Reservoir fracture pressure in Psi = Fracture Gradient X perforation Depth 20. p = Poisson’s Ratio

[0163] For final output calculation:

[0164] Tubing movement calculation are primarily the summation of 4 effects namely a. Piston effect

[0165] b. Buckling effect

[0166] c. Ballooning effect

[0167] d. Temperature effect

[0168] Now we use formulas for calculating each effect as following:

[0169] Note: All the primary and derivatives quantities are already defined and calculated above. a. Piston Effect

[0170] • F±= (dp— A^ x AP(— (dp— z40) x AP0, calculated in lbs (pounds) • ALt= = (^-) X [((71P- Ao) X 4P0) - ((Tip - Ad X 4P;))]

[0171]

[0172] b. Bucking Effect

[0173] A J_r2Ap ^pi~apoF

[0174] 2SEJ (Wt+Wo-W^

[0175] • yy _ ^pX(Ptl-Pt2)

[0176] “ (Wi + Wo-Ws)

[0177] . = AL2x g) x [2 - (i)],

[0178]

[0179] c. Ballooning Effect

[0180] . P3= 0.6 X ((4P0X Tl0) - (4P;X Ad),

[0181] .. C—2u\ (APi-^XAPa)

[0182] • AL3

[0183] 5= — X ‘ X L

[0184] \ E J {R2,

[0185] -l}

[0186] d. Temperature Effect• 4L4= L X a X & Tavg

[0187] • F4=Xj^X aLi, where L is length of tubing

[0188]

[0189] To calculate the final output:

[0190] 1. Due to Piston Effect

[0191] • Length change is:

[0192]

[0193] is in inches

[0194] • Force exerted is: F4in lbs pounds

[0195] 2. Due to Buckling Effect

[0196] • Length change is: 4L2is in inches

[0197] • Force change is: F2in lbs pounds

[0198] 3. Due to Ballooning Effect

[0199] • Length change is: 4L3is in inches

[0200] • Force change is: F3in lbs pounds

[0201] 4. Due to Temperature Effect

[0202] • Length change is: AL4is in inches

[0203] • Force change is: F4is in lbs pounds

[0204] 5. Total ALtotaichange = AL4+ 4L2+ ^3 + L4in inches

[0205] Hence total length change in feet is: ALLoLaiinches and feet

[0206] 6. Total force Ftota[ bring applied = F4+ F2+ F3+ F4lbs pounds

[0207] Hence total force being applied in lbs. (pounds) is Ftotai

[0208] 7. Total slack off force to be applied from surface to counter act the total tubing moment is Ftotai.

[0209] 8. The total Force demonstrated may be in negative representing an upward movement of the tubing due to applied forces. The reactive counter force required to apply from surface hence shall be denoted as a positive force (applied downwards).

[0210] In an exemplary embodiment, the particle size distribution (PSD) may comprise a following parameters:

[0211] 1. Now the user may add the number of Sieves, Sieve Size, Opening of the sieves in microns and Soil retained in gm(grams) unit.2. Now the user input may be converted into a table format with the columns namely Sieve No, Diameter (mm), Soil Retained (gm), Cumulative Mass Retained, Mass Retained, Sand Passing.

[0212] 3. The input parameters may correspond to Sieve No, Diameter (mm), Soil Retained (gm) while Cumulative Retained, Mass Retained, Sand Passing may be the derived parameters and their formulas embedded in the backend.

[0213] 4. Then the application may calculate dlO, d30, d40, d50, d60, d90, d95 using pre-defined functions and calculation formulas.

[0214] 5. Then Uniformity coefficient Uc: d40 / d90 may be calculated.

[0215] 6. Then Sorting Coefficient Sc: dl0 / d95, % Gravel, % Fines, % Sand may be calculated. 7. The derived formulas:

[0216] • Cumulative Retain (gm): is the cumulative of all the soil retained.

[0217] • Mass Retain (%): the individual values are calculated using ( Accumulative Retain (gm) -i nn

[0218] - Total accumulati ' -ve retai - —n ( 7gm T) / ) 100

[0219]

[0220] • Sand passing % = 100 — Mass Retain (%))

[0221] • dlO (mm)=Trend functionality for identifying the % in between 2 numbers to indicate the size below which 10%, of all particles are found.

[0222] • d30 (mm)=Trend functionality for identifying the % in between 2 numbers to indicate the size below which 30% of all particles are found.

[0223] • d40 (mm)=Trend functionality for identifying the % in between 2 numbers to indicate the size below which 40%, of all particles are found.

[0224] • d50 (mm)=Trend functionality for identifying the % in between 2 numbers to indicate the size below which 50%, of all particles are found.

[0225] • d60 (mm)=Trend functionality for identifying the % in between 2 numbers to indicate the size below which 60%, of all particles are found.

[0226] • d90 (mm)=Trend functionality for identifying the % in between 2 numbers to indicate the size below which 90%, of all particles are found.

[0227] • d95 (mm)=Trend functionality for identifying the % in between 2 numbers to indicate the size below which 95%, of all particles are found.

[0228] d40

[0229] • Uniformity Co-efficient* = Uc. — (both d40 and d90 are calculated above)• Sorting Co-efficient* = Sc: — (both dlO and d95 are calculated above) • %Gravel (carry forwarded from previously calculated mass retain)

[0230] • %fines (carry forwarded from max sand passing %)

[0231] • %sand (total sum of % gravel and % fines)

[0232] 8. Then the application may calculate and display Fines <5 (gm) and Screen Size (microns). 9. Then the application may be configured to display the output which may define the screen size in microns that will be suitable to use for this type of sand.

[0233] Referring to FIG. 3, a flowchart that illustrates a method (300) for providing an application for wellbore schematic designing and managing well completion, in accordance with at least one embodiment of the present subject matter. The method (300) may be implemented by the application server (102) including one or more processors (202) and the memory (204) communicatively coupled to the processor (202) and the memory (204) is configured to store processor-executable programmed instructions, caused the processor to perform the following steps.

[0234] At step (302), the processor (202) is configured to display a a user interface (UI). Further, the UI may comprise a canvas and a well schematic library comprising one or more well components.

[0235] At step (304), the processor (202) is configured to receive one or more inputs from a user to position the one or more well components on the canvas for designing the wellbore.

[0236] At step (306), the processor (202) is configured to generate a wellbore schematic design using the one or more well components based on the received one or more inputs.

[0237] At step (308), the processor (202) is configured to the wellbore schematic design on the canvas of the UI.

[0238] At step (310), the processor (202) is configured to receive a plurality of simulation parameters associated with the wellbore design from the user.

[0239] At step (312), the processor (202) is configured to compute at least one of a tubing movement, a particle size distribution, a torque and drag a PVT Analysis, a Well barrier for protection of the wellbore based on the received plurality of simulation parameters.

[0240] At step (314), the processor (202) is configured to determine one or more alterations to the wellbore schematic design based on the computed at least one of the tubing movement, the particle sizedistribution, the torque and drag the PVT Analysis, the Well barrier for protection of the wellbore At step (316), the processor (202) is configured to perform the one or more alterations to the wellbore schematic design for managing the well completion by performing various calculations.

[0241] Let us delve into a detailed working example of the present disclosure.

[0242] Example 01: X is a user who wants to design and manage a wellbore schematic designs for a new oil / gas extraction projects.

[0243] Now, X is presented with a user interface (UI) that displays a canvas for visual design and a well schematic library. Further, the library corresponds to various well components such as casing, tubing, wellhead, packers, sliding sleeve doors, landing nipples, sand screens, reservoir barrier valves, but not limited to pumps, and other essential elements used in well construction. Further, X selects the components required for the wellbore design based on the wells specifications, including the components required to be installed as per the needs. Further, X places the components on the canvas, arranging them to form an initial design for the wellbore. Further, the system (100) generates the wellbore design in real-time, using X’s inputs, and displays it on the UI. Further, this visual representation serves as the foundation for further analysis and refinement, allowing X to evaluate the initial design before proceeding.

[0244] Further, with the initial wellbore design displayed on the canvas, the application prompts X to input a series of simulation parameters. Further, the parameters correspond to factors such as expected pressures at different depths, fluid types (e.g., gas, oil, water), temperature ranges, and production rates. Further, the system (100) may request data regarding the surrounding geological conditions, such as rock formation characteristics, permeability, and porosity. Once X provides the necessary inputs, the system (100) uses this data to perform simulations, calculating key performance factors like tubing movement, particle size distribution, torque and drag, PVT (pressure, volume, and temperature) analysis, and the design of well barriers for protection against unwanted fluid migration, all of the above are calculated separately and not in relation to each other. Further, these simulations offer insights into how the wellbore will perform under various operational conditions, helping identify potential issues before the well operations.

[0245] The system (100) presents the simulation results, which may highlight specific conditions such as excessive forces or pressures applied in the tubing, excessive torque and drag, a recommended size ofSand Screen opening based on the particle size distribution Similarly, the PVT analysis indicates if the pressure and temperature conditions are outside of optimal ranges,. Further, X may review these suggestions and make informed decisions about which changes to implement, ensuring the wellbore will function optimally during production.

[0246] After X approves the changes, and updates in the system (100) the alterations to the wellbore design. Further, the updated design is then reflected on the UI, with all modifications clearly shown on the canvas. Further, the system (100) may run additional simulations to confirm that the adjustments have resolved the previously identified issues. This iterative process of simulation, review, and adjustment continues until the wellbore design meets the desired performance criteria. Once finalized, the wellbore design is optimized for efficient operation, considering factors such as safety, cost, and environmental impact. The application helps X ensure that the well is prepared for the challenging conditions of oil / gas extraction, ultimately leading to a more efficient, cost-effective, and safer drilling, completion and production process.

[0247] By integrating continuous simulation and dynamic design feedback, the application empowers X to make data-driven decisions during wellbore design. It not only facilitates the creation of a customized, optimized well design but also helps manage potential risks associated with well completion. This approach ultimately results in a more reliable and cost-efficient wellbore that can withstand the challenges of extraction, ensuring the success of the project.

[0248] In summary, the present disclosure provides a comprehensive solution for wellbore schematic design and management, emphasizing adaptability, real-time simulation, and user-centric design. This approach ensures that wellbore designs can be continuously optimized based on dynamic inputs and simulations, ultimately enhancing the efficiency, safety, and cost-effectiveness of the well completion process.

[0249] A person skilled in the art will understand that the scope of the disclosure is not limited to scenarios based on the aforementioned factors and using the aforementioned techniques and that the examples provided do not limit the scope of the disclosure.

[0250] FIG. 4 illustrates a block diagram of an exemplary computer system (401) for implementing embodiments consistent with the present disclosure.

[0251] Variations of a computer system (401) may be used for performing the one or more transactions. Thecomputer system (401) may comprise a central processing unit (“CPU” or “processor”) (402). The processor (402) may comprise at least one data processor for executing program components for executing user or system generated requests. A user may include a person, a person using a device such as those included in this disclosure, or such a device itself. Additionally, the processor (402) may include specialized processing units such as integrated system (bus) controllers, memory management control units, floating point units, graphics processing units, digital signal processing units, or the like. In various implementations, the processor (402) may include a microprocessor, such as AMD Athlon, Duron or Opteron, ARM’s application, embedded or secure processors, IBM PowerPC, Intel’s Core, Itanium, Xeon, Celeron or other line of processors, for example. Accordingly, the processor (402) may be implemented using a mainframe, distributed processor, multi-core, parallel, grid, or other architectures. Some embodiments may utilize embedded technologies like application-specific integrated circuits (ASICs), digital signal processors (DSPs), or Field Programmable Gate Arrays (FPGAs), for example.

[0252] Processor (402) may be disposed of in communication with one or more input / output (VO) devices via an VO interface (403). Accordingly, the I / O interface (403) may employ communication protocols / methods such as, without limitation, audio, analog, digital, monoaural, RCA, stereo, IEEE-1394, serial bus, universal serial bus (USB), infrared, PS / 2, BNC, coaxial, component, composite, digital visual interface (DVI), high-definition multimedia interface (HDMI), RF antennas, S-Video, VGA, IEEE 802. n / b / g / n / x, Bluetooth, cellular (e.g., code-division multiple access (CDMA), highspeed packet access (HSPA+), global system for mobile communications (GSM), long-term evolution (LTE), WiMAX, or the like, for example.

[0253] Using the I / O interface (403), the computer system (401) may communicate with one or more VO devices. For example, the input device (404) may be an antenna, keyboard, mouse, joystick, (infrared) remote control, camera, card reader, fax machine, dongle, biometric reader, microphone, touch screen, touchpad, trackball, sensor (e.g., accelerometer, light sensor, GPS, gyroscope, proximity sensor, or the like), stylus, scanner, storage device, transceiver, video device / source, or visors, for example. Likewise, an output device (405) may be a user’s smartphone, tablet, cell phone, laptop, printer, computer desktop, fax machine, video display (e.g., cathode ray tube (CRT), liquid crystal display (LCD), light- emitting diode (LED), plasma, or the like), or audio speaker, for example. In some embodiments, a transceiver (406) may be disposed in connection with the processor (402). The transceiver (406) may facilitate various types of wireless transmission or reception. For example, thetransceiver (406) may include an antenna operatively connected to a transceiver chip (example devices include the Texas Instruments® WiLink WL1283, Broadcom® BCM4750IUB8, Infineon Technologies® X-Gold 618-PMB9800, or the like), providing IEEE 802.11a / b / g / n, Bluetooth, FM, global positioning system (GPS), and / or 2G / 3G / 5G / 6G HSDPA / HSUPA communications, for example.

[0254] In some embodiments, the processor (402) may be disposed in communication with a communication network (408) via a network interface (407). The network interface (407) is adapted to communicate with the communication network (408). The network interface (407) may employ connection protocols including, without limitation, direct connect, Ethernet (e.g., twisted pair 10 / 100 / 1000 Base T), transmission control protocol / internet protocol (TCP / IP), token ring, or IEEE 802.11a / b / g / n / x, for example. The communication network (408) may include, without limitation, a direct interconnection, local area network (LAN), wide area network (WAN), wireless network (e.g., using Wireless Application Protocol), or the Internet, for example. Using the network interface (407) and the communication network (408), the computer system (401) may communicate with devices such as shown as a laptop (409) or a mobile / cellular phone (410). Other exemplary devices may include, without limitation, personal computer(s), server(s), fax machines, printers, scanners, various mobile devices such as cellular telephones, smartphones (e.g., Apple iPhone, Blackberry, Android-based phones, etc.), tablet computers, desktop computers, eBook readers (Amazon Kindle, Nook, etc.), laptop computers, notebooks, gaming consoles (Microsoft Xbox, Nintendo DS, Sony PlayStation, etc.), or the like. In some embodiments, the computer system (401) may itself embody one or more of these devices.

[0255] In some embodiments, the processor (402) may be disposed in communication with one or more memory devices (e.g., RAM 513, ROM 514, etc.) via a storage interface (412). The storage interface (412) may connect to memory devices including, without limitation, memory drives, removable disc drives, etc., employing connection protocols such as serial advanced technology attachment (SATA), integrated drive electronics (IDE), IEEE- 1394, universal serial bus (USB), fiber channel, small computer systems interface (SCSI), etc. The memory drives may further include a drum, magnetic disc drive, magneto-optical drive, optical drive, redundant array of independent discs (RAID), solid-state memory devices, or solid-state drives, for example.

[0256] The memory devices may store a collection of program or database components, including, withoutlimitation, an operating system (416), user interface application (417), web browser (418), mail client / server (419), user / application data (420) (e.g., any data variables or data records discussed in this disclosure) for example. The operating system (416) may facilitate resource management and operation of the computer system (401). Examples of operating systems include, without limitation, Apple Macintosh OS X, UNIX, Unix-like system distributions (e.g., Berkeley Software Distribution (BSD), FreeBSD, NetBSD, OpenBSD, etc.), Linux distributions (e.g., Red Hat, Ubuntu, Kubuntu, etc.), IBM OS / 2, Microsoft Windows (XP, Vista / 7 / 8, etc.), Apple iOS, Google Android, Blackberry OS, or the like.

[0257] The user interface (417) is for facilitating the display, execution, interaction, manipulation, or operation of program components through textual or graphical facilities. For example, user interfaces (417) may provide computer interaction interface elements on a display system operatively connected to the computer system (401), such as cursors, icons, check boxes, menus, scrollers, windows, or widgets, for example. Graphical user interfaces (GUIs) may be employed, including, without limitation, Apple Macintosh operating systems’ Aqua, IBM OS / 2, Microsoft Windows (e.g., Aero, Metro, etc.), Unix X-Windows, or web interface libraries (e.g., ActiveX, Java, JavaScript, AJAX, HTML, Adobe Flash, etc.), for example.

[0258] In some embodiments, the computer system (401) may implement a web browser (418) stored program component. The web browser (418) may be a hypertext viewing application, such as Microsoft Internet Explorer, Google Chrome, Mozilla Firefox, Apple Safari, or Microsoft Edge, for example. Secure web browsing may be provided using HTTPS (secure hypertext transport protocol), secure sockets layer (SSL), Transport Layer Security (TLS), or the like. Web browsers may utilize facilities such as AJAX, DHTML, Adobe Flash, JavaScript, Java, NodeJS, React or application programming interfaces (APIs), for example. In some embodiments the computer system (401) may implement a mail client / server (419) stored program component. The mail server (419) may be an Internet mail server such as Microsoft Exchange, or the like. The mail server may utilize facilities such as ASP, ActiveX, ANSI C++ / C#, Microsoft. NET, CGI scripts, Java, JavaScript, PERL, PHP, Python, or WebObjects, for example. The mail server (419) may utilize communication protocols such as internet message access protocol (IMAP), messaging application programming interface (MAPI), Microsoft Exchange, post office protocol (POP), simple mail transfer protocol (SMTP), or the like. In some embodiments, the computer system (401) may implement a mail client (419) stored program component. The mail client (419) may be a mail viewing application, such as Apple Mail,Microsoft Entourage, Microsoft Outlook, or Mozilla Thunderbird.

[0259] In some embodiments, the computer system (401) may store user / application data (420), such as the data, variables, records, or the like as described in this disclosure. Such databases may be implemented as fault-tolerant, relational, scalable, secure databases such as Oracle or Sybase, for example. Alternatively, such databases may be implemented using standardized data structures, such as an array, hash, linked list, struct, structured text file (e.g., XML), table, or as object-oriented databases (e.g., using ObjectStore, Poet, Zope, etc.). Such databases may be consolidated or distributed, sometimes among the various computer systems discussed above in this disclosure. It is to be understood that the structure and operation of any computer or database component may be combined, consolidated, or distributed in any working combination.

[0260] Furthermore, one or more computer-readable storage media may be utilized in implementing embodiments consistent with the present invention. A computer-readable storage medium refers to any type of physical memory on which information or data readable by a processor may be stored. Thus, a computer-readable storage medium may store instructions for execution by one or more processors, including instructions for causing the processor(s) to perform steps or stages consistent with the embodiments described herein. The term “computer readable medium” should be understood to include tangible items and exclude carrier waves and transient signals, i.e., non -transitory. Examples include Random Access Memory (RAM), Read- Only Memory (ROM), volatile memory, non-volatile memory, hard drives, Compact Disc (CD) ROMs, Digital Video Disc (DVDs), flash drives, disks, and any other known physical storage media.

[0261] Various embodiments of the disclosure encompass numerous advantages including methods and systems to provide an application for wellbore schematic designing and managing well completion. The disclosed method and system have several technical advantages, but not limited to the following: Enhanced Design Flexibility: The user interface (UI) allows for dynamic, interactive positioning of well components, enabling users to customize wellbore designs with precision and ease using single click, click, and touch inputs.

[0262] Comprehensive Simulation: The system computes critical parameters such as tubing movement, torque and drag, particle size distribution, and well barriers, providing a robust simulation environment for optimizing wellbore designs and improving operational efficiency.Multi-User Collaboration: The platform supports a collaborative environment where multiple users can concurrently work (work and view) on the same design with role-based access, improving teamwork and decision-making during the well completion process.

[0263] Automated Wellbore Design Adjustments: The method may automatically suggests alterations to the wellbore design based on predefined simulation models, historical data, and best practices, helping users avoid costly mistakes and optimize the design quickly.

[0264] Cloud-Based Access and Scalability: Being hosted on a cloud-based SaaS platform, the application ensures that users can access their wellbore designs and management tools from anywhere, with the flexibility to scale based on their needs and subscription level.

[0265] In summary, these technical advantages solve the technical problem of efficiently designing and managing wellbore completions by providing a flexible, scalable, and dynamic system for optimizing wellbore design parameters. The method and system address key challenges such as design complexity, real-time simulation adjustments, and collaborative workflow, enabling a more resilient, cost-effective, and responsive solution for well completion planning and management. By ensuring precise design customization, real-time simulation updates, and seamless collaboration, the invention significantly improves the efficiency, accuracy, and adaptability of wellbore completion processes. The claimed invention for designing and managing wellbore completions addresses the need for a dynamic, scalable, and efficient wellbore design and management system. It ensures the optimal distribution of well completion components and design parameters, preventing errors, delays, and inefficiencies in the design process. By incorporating real-time adaptability, cost optimization, and enhanced system resilience, the invention fulfils the demand for a reliable and cost-effective solution in complex wellbore completion environments, improving the accuracy, flexibility, and overall success of wellbore designs.

[0266] Furthermore, the invention involves a non-trivial combination of technologies and methodologies that provide a technical solution for a technical problem. While individual components like processors, databases, user interface, display are well-known in the field of computer science, their integration into a comprehensive system for providing an application for wellbore schematic designing and managing well completion brings about improvement and technical advancement in the field of wellbore schematic designing environments.In light of the above-mentioned advantages and the technical advancements provided by the disclosed method and system, the claimed steps as discussed above are not routine, conventional, or well understood in the art, as the claimed steps enable the following solutions to the existing problems in conventional technologies. Further, the claimed steps clearly bring an improvement in the functioning of the device itself as the claimed steps provide a technical solution to a technical problem.

[0267] The present disclosure may be realized in hardware, or a combination of hardware and software. The present disclosure may be realized in a centralized fashion, in at least one computer system, or in a distributed fashion, where different elements may be spread across several interconnected computer systems. A computer system or other apparatus adapted for carrying out the methods described herein may be suited. A combination of hardware and software may be a general-purpose computer system with a computer program that, when loaded and executed, may control the computer system such that it carries out the methods described herein. The present disclosure may be realized in hardware that comprises a portion of an integrated circuit that also performs other functions.

[0268] A person with ordinary skills in the art will appreciate that the systems, units, modules, and submodules have been illustrated and explained to serve as examples and should not be considered limiting in any manner. It will be further appreciated that the variants of the above disclosed system elements, modules, and other features and functions, or alternatives thereof, may be combined to create other different systems or applications.

[0269] Those skilled in the art will appreciate that any of the aforementioned steps and / or system modules may be suitably replaced, reordered, or removed, and additional steps and / or system modules may be inserted, depending on the needs of a particular application. In addition, the systems of the aforementioned embodiments may be implemented using a wide variety of suitable processes and system modules, and are not limited to any particular computer hardware, software, middleware, firmware, microcode, and the like. The claims can encompass embodiments for hardware and software, or a combination thereof.

[0270] While the present disclosure has been described with reference to certain embodiments, it will be understood by those skilled in the art that various changes may be made, and equivalents may be substituted without departing from the scope of the present disclosure. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the present disclosure without departing from its scope. Therefore, it is intended that the present disclosure is notlimited to the particular embodiment disclosed, but that the present disclosure will include all embodiments falling within the scope of the appended claims.

Claims

WE CLAIM:

1. A method (300) for providing an application for wellbore schematic designing and managing well completion, the method (300) comprising:displaying (302), by a processor (202), a user interface (UI) comprising a canvas and a well schematic library comprising one or more well components;receiving (304), by the processor (202), one or more inputs from a user to position the one or more well components on the canvas for designing the wellbore;generating (306), by the processor (202), a wellbore design using the one or more well components based on the received one or more inputs;displaying (308), by the processor (202), the wellbore design on the canvas of the UI; receiving (310), by the processor (202), a plurality of simulation parameters associated with the wellbore design from the user;computing (312), by the processor (202), at least one of a tubing movement calculation, a particle size distribution, a torque and drag, a PVT Analysis, a Well barrier for protection of the wellbore based on the received plurality of simulation parameters;determining (314), by the processor (202), one or more alterations to the wellbore design based on the computed at least one of the tubing movement calculation, the particle size distribution, the torque and drag, the PVT Analysis, the Well barrier for protection of the wellbore; andperforming (316), by the processor (302), the one or more alterations to the wellbore design for managing the well completion.

2. The method (300) as claimed in claim 1, comprisingreceiving one or more design modifications to the wellbore design from a user; dynamically calculating and adjusting the tubing movement, the particle size distribution, the torque and drag, a PVT Analysis, a Well barrier for protection of the wellbore based on the one or more design modifications using one or more machine learning techniques.receiving a PSD input for at least one or more samples associated with a type of sand for sand screen selection of the wellbore completion from the user corresponding to number of sieves, diameter of the sieves and soil retained;determining a Cumulative Retained percentage, a Mass Retain percentage, a Sand Passing percentage based on the received PSD input;computing at least one of a particle size distribution, Uniformity coefficient (Uc), a sorting coefficient (Sc), gravel percentage, fines percentage, and sand percentage based on the Accumulative Retain, the Mass Retain, and the Sand Passing; anddefining a screen size that is suitable to use for the wellbore completion for the type of sand based on the computation.

3. The method (300) as claimed in claim 1, wherein the one or more well components comprises at least one of a wellheads, casing, tubing’s, safety valves, injection mandrels and ports, packers, sliding sleeve, other downhole valve and chokes, tubing plugs, sand screens, flow control valves, liner hangers, bridge plugs, cement and sand plugs and all other well completion components, wherein the one or more inputs comprises at least one of a single click input, a drag-and-drop point, a mouse hover, a touch input, wherein the one or more well components being positioned on the canvas using the single click input, wherein the one or more well components correspond to one or more templates designed and stored in the well schematic library, wherein the one or more templates on the canvas are pre-loaded for at least one of a vertical wells, deviated wells, horizontal wells, multilateral wells, for customization based on pre-defined well design conditions.

4. The method (300) as claimed in claim 1, wherein the canvas within the UI is configured to:providing a snap-to-grid functionality, enabling the one or more well components to align automatically or manually with predefined grid lines for precise placement, wherein the UI is configured to provide one or more interactive tools to enable the user for dynamically positioning the one or more well components within the canvas, and wherein the UI comprises one or more interactive fields to capture a first information associated with a customer and a second information associated with the wellbore design;organize a plurality of schematic layers for different aspects of wellbore design, wherein the plurality of schematic layers corresponds to at least one of surface equipment, downhole completion, or production equipment;generating a 2D representation or 3D representation of the wellbore design comprising the one or more well components and displaying the 2D representation or the 3D representation on a display device of an electronic device of the user;generating a report of the wellbore design after performing the one or more alterations, wherein the one or more alterations comprises at least one of adjusting, scaling, repositioning the wellbore design and the one or more well components;displaying the generated report to the user, wherein the report comprises design data associated with the wellbore design, one or more well component specifications, tubing parameters, PSD analysis results, or a combination thereof;providing a collaborative environment within the UI to a plurality of users where in realtime the plurality of user concurrently perform operations for wellbore schematic designing and managing well completion, wherein the plurality of users being provided with role based access for different levels of editing and viewing privileges; andrecommending the one or more alterations to the wellbore design based on predefined simulation models, historical data, and best practices derived from previous well completion designs.

5. The method (300) as claimed in claim 1, wherein the plurality of simulation parameters associated with the tubing movement comprises material of pipe, Initial Tubing Pressure Pi1, Final tubing pressure Pi2, Initial Annulus Pressure Po1, Final Annulus Pressure Po2, Packer setting depth h, Tubing fluid initial ρi1, Tubing fluid final ρi2, Annular fluid initial ρo1, Annular fluid final ρo2, Youngs Modulus E1, Weight of tubing Ws, Surface temperature Ts, Bottom Hole temperature Tbh, Geothermal Gradient, Thermal expansion coefficient α, Tubing ID, Tubing OD, Casing ID, Seal Bore packer ID, Length of Tubing L, perforation depth, and Fracture gradient, wherein the tubing movement being computed based on a Piston Effect, a Bucking Effect, a Ballooning Effect, a Temperature Effect, a Packer set Effect, wherein each of the Piston Effect, the Bucking Effect, the Ballooning Effect, the Temperature Effect, the Packer set Effect being computed based on the plurality of simulation parameters associated with the tubing movement.

6. The method (300) as claimed in claim 1, wherein the plurality of simulation parameters associated with the torque and drag of the wellbore comprises wellbore geometry, fluid properties, string configuration, rotational speed, bit weight, friction coefficients, and formation characteristics, wherein the torque and drag of the wellbore being computed at least one of a mathematical model or computational algorithm that takes into account the real-time dynamics of the drilling or completions operation, including axial forces, rotational forces, torsional forces, and frictional losses between the drill string or completion string and wellbore walls or openhole.

7. The method (300) as claimed in claim 1, wherein the application for wellbore schematic designing and managing well completion being hosted on a server, wherein the server is cloud based, wherein the user interface (UI) being accessible via a cloud hosted SaaS platform, and wherein the application being accessible to the user on a subscription basis for a pre-defined monetary compensation.

8. The method (300) as claimed in claim 1, comprises automatically or manually positioning on the canvas a first well component with respect to a second well component based on a working relation associated with each of the first well component and the second well component.

9. The method (300) as claimed in claim 1, comprisesreceiving a barrier input from the user via the UI, wherein barrier input corresponds to information of a first barrier and a second barrier associated with the generated wellbore design, the information of the first barrier comprises a well fluid column, casing size ID and OD, tubing size ID and OD, perforation depth, reservoir pressure and temperature, Cement;calculating a pressure exerted by the fluid column in the first barrier based on the information of the first barrier, a density of fluid, an acceleration due to gravity, and a perforation depth;comparing the calculated volume with a pre-defined threshold associated with a pore pressure; andproviding an alert to the user if the calculated pressure is less than the pre-defined threshold associated with the pore pressure;computing a plurality of parameters associated with the second barrier based on the the information of the second barrier, wherein the second barrier corresponds to Casing, liner, shear ram, intermediate casing, Subsurface Safety Valve, Packer, Flow Control Valves, Reservoir Barrier Valve, wherein the information of the second barrier comprises casing size ID and OD, tubing size ID and OD, perforation depth, and reservoir pressure.

10. A system (100) to provide an application for wellbore schematic designing and managing well completion, the system (100) comprises:a processor (202), a memory (204) communicatively coupled with the processor (202), wherein the memory (204) is configured to store one or more executable instructions, which cause the processor (202) to:display a user interface (UI) comprising a canvas and a well schematic library comprising one or more well components;receive one or more inputs from a user to position the one or more well components on the canvas for designing the wellbore;generate a wellbore design using the one or more well components based on the received one or more inputs;display the wellbore design on the canvas of the UI;receive a plurality of simulation parameters associated with the wellbore design from the user;compute at least one of a tubing movement, a particle size distribution, a torque and drag, a PVT Analysis, a Well barrier for protection of the wellbore based on the received plurality of simulation parameters;determine, one or more alterations to the wellbore design based on the computed at least one of the tubing movement, the particle size distribution, the torque and drag, a PVT Analysis, a Well barrier for protection of the wellbore; andperform the one or more alterations to the wellbore design for managing the well completion.

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