System and method for deploying fiber optic cable using in-situ cured pipe lining

Abstract

A system can include a wellbore (10) extending to a first depth within a formation. Further, an in-situ cured pipe liner (100) can be coupled to a wall (11) of the wellbore. One or more fiber optic cables (101, 102, 103) are embedded in the in-situ cured pipe liner (100) to monitor curing of the in-situ cured pipe liner (100) and to record well data. The one or more fiber optic cables (101, 102, 103) can be used to continuously monitor the wellbore (10) during a method of lining the wellbore. The method of lining the wellbore (10) can include inserting the in-situ cured pipe liner (100) into the wellbore, forcing the in-situ cured pipe liner (100) against the wall (11) of the wellbore, curing the in-situ cured pipe liner (100), monitoring the curing of the in-situ cured pipe liner (100) with the one or more fiber optic cables (101, 102, 103) embedded in the in-situ cured pipe liner (100), and coupling the in-situ cured pipe liner (100) to the wall (11) of the wellbore.

Description

Background Technology

[0001] In the oil and gas industry, liners are used in wells to line the wellbore. Similar to casing, liners protect and reinforce the wellbore. In some cases, fiber optic cables extend down the liner to transmit data from inside the wellbore to the surface. Fiber optic cables can refer to optical cables or fiber optic cables that transmit data signals in the form of light. Fiber optic cables consist of optical fibers within a sheath. For example, the optical fibers are typically individually coated with a plastic layer and contained within a sheath (i.e., a protective tube) suitable for the environment in which the fiber optic cable will operate.

[0002] Distributed acoustic sensing (DAS) utilizes telecommunications or engineering fiber optic cables, transforming these cables into a dense array of single-component strain or strain rate sensors. DAS has been applied to vertical seismic profiles (VSPs) to provide seismic wavefield recordings along the entire well depth. Furthermore, fiber optic cables consolidated behind the casing within the well allow for VSP recording during well operations and provide excellent data repeatability during time-lapse seismic exploration. Applications of DAS VSPs include marine and terrestrial reservoir monitoring, hydraulic fracturing monitoring, monitoring for carbon capture, utilization and storage (CCUS) applications, and assessment of geothermal sites. The density of DAS channels provides opportunities for in-situ inversion of elastic properties.

[0003] However, due to the high cost of permanent fiber optic installations, temporary fiber optic installations have become increasingly common. Temporary fiber optic installations include fiber optic cables mounted on wire ropes and one-time bare fiber installations. Although there is a slight decrease in quality, such installations have proven valuable in some applications due to their relatively low deployment cost. Other current drilling applications, such as fracturing monitoring, also require fiber optic cables to be secured behind the casing, making the cost of deploying fiber optic cables in each well prohibitively high, and making permanent deployment in existing wells virtually impossible. Furthermore, expandable fiber optic cables cannot provide sufficient coupling for accurate VSP and strain sensing. Summary of the Invention

[0004] This summary is provided to introduce a series of concepts that will be further described in the following detailed description. This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to help limit the scope of the claimed subject matter.

[0005] In one aspect, embodiments disclosed in this specification relate to a method for lining a wellbore. The method may include: inserting an in-situ cured pipe liner into the wellbore; forcing the in-situ cured pipe liner against the wall of the wellbore; curing the in-situ cured pipe liner; monitoring the curing of the in-situ cured pipe liner using one or more optical fiber cables embedded in the in-situ cured pipe liner; coupling the in-situ cured pipe liner to the wall of the wellbore; and continuously monitoring the wellbore using the one or more optical fiber cables.

[0006] In another aspect, the embodiments disclosed in this specification relate to a method for lining a wellbore. The method may include: inverting an in-situ cured pipe liner into the wellbore; forcing the in-situ cured pipe liner against the wall of the wellbore; curing the in-situ cured pipe liner; monitoring the curing of the in-situ cured pipe liner using one or more optical fiber cables embedded in the in-situ cured pipe liner; coupling the in-situ cured pipe liner to the wall of the wellbore; and continuously monitoring the wellbore using the one or more optical fiber cables.

[0007] In another aspect, embodiments disclosed in this specification relate to a system that may include: a wellbore extending to a first depth within a formation; an in-situ cured pipe liner coupled to a wall of the wellbore; and one or more fiber optic cables embedded in the in-situ cured pipe liner for monitoring the curing of the in-situ cured pipe liner and recording well data. The one or more fiber optic cables may be used to continuously monitor the wellbore during the process of lining the wellbore. The method of lining the wellbore may include: inserting the in-situ cured pipe liner into the wellbore; forcing the in-situ cured pipe liner against a wall of the wellbore; curing the in-situ cured pipe liner; monitoring the curing of the in-situ cured pipe liner using the one or more fiber optic cables embedded in the in-situ cured pipe liner; and coupling the in-situ cured pipe liner to a wall of the wellbore.

[0008] Any combination of the various embodiments and implementations disclosed in this specification can be used in other embodiments consistent with this disclosure. Further aspects and advantages of the invention will become apparent from the following description and the appended claims. Attached Figure Description

[0009] The following is a description of the figures in the accompanying drawings. In the figures, the same reference numerals identify similar elements or actions. The dimensions and relative positions of the elements in the figures are not necessarily drawn to scale. For example, the shapes and angles of various elements are not necessarily drawn to scale, and some elements may be arbitrarily enlarged and positioned to improve the readability of the drawings. Furthermore, the shapes of the elements drawn are not necessarily intended to convey any information about the actual shape of the elements, but are chosen solely for ease of identification in the figures.

[0010] Figure 1 A block diagram is shown of a liner having one or more optical fiber cables according to one or more embodiments of the present disclosure.

[0011] Figure 2 One or more embodiments according to this disclosure are shown. Figure 1 A diagram showing the solidified inner lining abutting against the wellbore.

[0012] Figure 3 A flowchart is shown according to one or more embodiments of the present disclosure.

[0013] Figures 4 to 10 The illustration shows one or more embodiments of the present disclosure applied to well sites. Figure 3 The implementation of the flowchart.

[0014] Figure 11 A block diagram of a flip-up liner having one or more optical fiber cables according to one or more embodiments of the present disclosure is shown.

[0015] Figure 12 One or more embodiments according to this disclosure are shown. Figure 11 A diagram showing the inverted lining solidified against the wellbore.

[0016] Figure 13 A flowchart is shown according to one or more embodiments of the present disclosure.

[0017] Figures 14 to 18 The illustration shows one or more embodiments of the present disclosure applied to well sites. Figure 13 The implementation of the flowchart.

[0018] Figure 19 A computer system according to one or more embodiments of the present disclosure is shown. Detailed Implementation

[0019] Embodiments of this disclosure will now be described in detail with reference to the accompanying drawings. However, those skilled in the art will recognize that embodiments and examples can be practiced without one or more of these specific details, or by other methods, components, materials, etc. For the sake of coherence and brevity, the same or similar reference numerals may be used for the same or similar objects in various figures. As used herein, the terms “coupled” or “coupled to” or “connected” or “connected to,” “attached” or “attached to” may indicate the establishment of a direct or indirect connection, and are not limited thereto unless expressly indicated.

[0020] As used herein, fluid may refer to slurry, liquid, gas, and / or mixtures thereof. It should be further understood that the various embodiments described herein can be used at various stages of well (onshore and / or offshore), such as rig site preparation, drilling, completion, well abandonment, etc., and can be used in other environments, such as workover rigs, fracturing units, well testing units, and oil and gas production units, without departing from the scope of this disclosure. Furthermore, the embodiments disclosed herein are described using the terminology of a reference to a vertical wellbore, but any terminology specifying direction should not be considered as limiting the scope of this disclosure. For example, embodiments of this disclosure may refer to a horizontal wellbore. It should be further understood that the various embodiments described herein can be used in various orientations, such as inclined, inverted, horizontal, vertical, etc., and can be used in other environments, such as the seabed, without departing from the scope of this disclosure. These embodiments are described only as examples of useful applications and are not limited to any specific details of the embodiments described herein.

[0021] In one or more embodiments, this disclosure relates to systems and methods for deploying fiber optic cables during the installation of a liner in a well. More specifically, embodiments disclosed herein relate to coupling fiber optic cables to the well using fiber optic cables embedded in or adjacent to the liner. Furthermore, the liner is a cured in-situ pipe (CIPP) liner, which is used to secure the liner against the wellbore. During the CIPP procedure and after the liner is installed in the well, fiber optic cables are used to record well data via distributed acoustic sensing (DAS) and distributed temperature sensing (DTS). In some embodiments, the CIPP liner may be flipped within the wellbore. Therefore, the systems and methods disclosed herein improve the coupling of a CIPP liner with fiber optic cables to the wellbore. In one or more embodiments, the method using a CIPP liner with fiber optic cables enables continuous well monitoring without human intervention and reduces the operating costs associated with conventional methods of well monitoring using fiber optic cables. In general, CIPP liners with fiber optic cables, as described herein, can reduce product engineering, shorten assembly time, reduce hardware costs, and reduce weight and envelope.

[0022] Now refer to Figure 1 and Figure 2 In one or more embodiments, a block diagram of a cured in-situ pipe (CIPP) liner 100 having at least one fiber optic cable 101 to 103 within a wellbore 10 is shown. The wellbore 10 is formed by drilling into the formation to define a channel for transporting fluids. Furthermore, the walls 11 of the wellbore 10 are defined by the formation itself. Although the wellbore 10 is shown as vertically oriented, this is for illustrative purposes only, and the wellbore 10 may include horizontal sections. Furthermore, for simplicity only, only a portion of the wellbore 10 is shown. In some embodiments, a casing string may be consolidated against the wellbore 10 such that the CIPP liner 100 is consolidated against the casing string rather than against the wellbore 10.

[0023] In one or more embodiments, the CIPP liner 100 is a tube 100a impregnated or embedded with resin. The tube 100a of the CIPP liner 100 can be made of various materials, such as felt, glass fiber, carbon fiber, textiles (e.g., cellulose (cotton, viscose, etc.), polyester, polyamide, elastomers (e.g., spandex)), polyethylene (PE), composite materials, or combinations thereof. In some embodiments, the material of the tube 100a can be fiber-reinforced or braided. Furthermore, the resin can be a polyester resin, vinyl ester resin, epoxy resin, a combination thereof, or any type of thermosetting resin. Additionally, the resin may include fillers, such as inert fillers, to increase stiffness upon resin curing.

[0024] In some embodiments, an impregnation process may be performed to impregnate or embed resin within the tube 100a of the CIPP liner 100. For example, resin may first be pumped into the center of the tube 100a. Then, under vacuum, the resin migrates from the inner surface of the tube 100a to the outer surface of the tube 100a, thereby impregnating or embedding the resin along the entire length of the tube 100a. Furthermore, the inner and outer surfaces of the tube 100a may be coated with a thermoplastic polymer, such as thermoplastic polyolefin (TPO) or thermoplastic polyurethane (TPU), to retain the resin within the tube 100a during the impregnation process and to prevent resin loss during the installation of the CIPP liner 100.

[0025] During the impregnation process, fiber optic cables 101 to 103 may be embedded in the CIPP liner 100. For example, fiber optic cables 101 to 103 may be attached to or braided into tube 100a, such that when tube 100a is impregnated with resin, fiber optic cables 101 to 103 become embedded in tube 100a. In some embodiments, fiber optic cables 101 to 103 may first be attached to a mat, and then the mat may be attached to tube 100a. The mat may be a flat sheet made of felt, glass fiber, carbon fiber, textiles (e.g., cellulose (cotton, viscose, etc.), polyester, polyamide, elastomers (e.g., spandex)), polyethylene (PE), composite materials, or combinations thereof. Alternatively, fiber optic cables 101 to 103 may first be loosely suspended in the wellbore 10, and then the CIPP liner 100 may be placed in the wellbore to press the fiber optic cables 101 to 103 against the wall 11 of the wellbore 10.

[0026] In one or more embodiments, fiber optic cables 101 to 103 can be arranged to extend downward along tube 100a in various orientations. For example, the first fiber optic cable 101 can be arranged in an inner liner orientation, such that the first fiber optic cable 101 extends axially downward along the length of tube 100a in a relatively straight line. The second fiber optic cable 102 can be arranged in an oscillating orientation, such that the second fiber optic cable 102 extends downward along the length of tube 100a in a sinusoidal line. The third fiber optic cable 103 can be arranged in a random orientation, such that the third fiber optic cable 103 can extend downward along the length of tube 100a in various directions and shapes. For example, the third fiber optic cable 103 can be arranged downward along the length of tube 100a with various loops, curves, and straight lines. Furthermore, fiber optic cables 101 to 103 can be arranged in different configuration orientations, such as helical, multi-sinusoidal, straight, and combinations thereof, to record different components of the strain tensor. By extending the first fiber optic cable 101, the second fiber optic cable 102, and the third fiber optic cable 103 downwards along the tube 100a in various orientations, the fiber optic cables 101 to 103 provide data covering the entire length and circumference of the CIPP liner 100 to optimize distributed acoustic sensing (DAS) and distributed temperature sensing (DTS). It is also envisioned that each fiber optic cable 101 to 103 can be dedicated to either DAS or DTS mode. For example, the first fiber optic cable 101 and the third fiber optic cable 103 can be used in DAS mode, while the second fiber optic cable 102 can be used in DTS mode. Since the second fiber optic cable 102 can be used in DTS mode, it can have a helical configuration for more uniform coverage of the fiber optic region. In some embodiments, all fiber optic cables 101 to 103 can be used simultaneously in both DAS and DTS modes.

[0027] Fiber optic cables 101 to 103 also extend from one end of the conduit 100a. For example, a portion 101a to 103a of each fiber optic cable 101 to 103 extends axially outward from the end face 100b of the conduit 100a. Furthermore, the end face 100b of the conduit 100a may be located at the top end 10a of the shaft 10, such that portions 101a to 103a of each fiber optic cable 101 to 103 are not within the shaft 10. By ensuring that portions 101a to 103a of each fiber optic cable 101 to 103 are not within the shaft 10, corresponding measurement units or data acquisition units 101a to 103a can be connected to each fiber optic cable 101 to 103. In some embodiments, fiber optic cables 101 to 103 may be connected to a single data acquisition unit. The data acquisition units 101a to 103a may be fiber optic demodulators (e.g., photoelectric instruments) to allow for both static and dynamic monitoring applications. For example, if fiber optic cables 101 to 103 include fiber Bragg gratings (FBGs) in their cores, when light travels through the cables, a portion of the light will be reflected back to the fiber demodulator from the FBG, while the remaining light will pass through the FBG. Based on the received reflected light, the fiber demodulator can record and determine various parameters, such as temperature and strain, during DAS and DTS.

[0028] In some embodiments, the control system 104 may be connected to each data acquisition unit 101a to 103a. In some embodiments, the data acquisition units 101a to 103a may be integrated into the control system 104. The control system 104 may include hardware and / or software for monitoring and / or operating devices communicating with the wellbore 10. In particular, the control system 104 may be coupled to the data acquisition units 101a to 103a to collect data from the fiber optic cables 101 to 103 throughout the wellbore 10. In some embodiments, the control system 104 may include a programmable logic controller (PLC) that can control data transmission through the fiber optic cables 101 to 103, devices for expanding or curing the CIPP liner 100, and / or various hardware components throughout the wellbore 10. For example, the control system 104 may be used to configure each of the fiber optic cables 101 to 103 in DAS mode or DTS mode. Thus, the PLC may be a ruggedized computer system capable of withstanding vibration, extreme temperatures, humid conditions, and / or dusty conditions (e.g., conditions around the well site, such as well completion or drilling rig).

[0029] In one or more embodiments, the control system 104 may include functionality to display data and / or receive input from a user regarding well data recorded by a fiber optic cable. For example, the control system 104 may be user equipment, such as a personal computer, smartphone, and any other device coupled to a network, which acquires input from one or more users, for example, by providing a graphical user interface (GUI) for displaying data and / or receiving control instructions for operations at the wellbore 10. In some embodiments, data is transmitted via network elements coupled to the control system 104. Network elements may refer to various hardware components within a network, including switches, routers, hubs, or any other logical entity for unifying one or more physical devices on the network. For example, network elements and / or the control system 104 may be... Figure 19 Computing systems similar to those described in the accompanying description.

[0030] like Figure 1 As shown, the CIPP liner 100 is inserted into the wellbore 10. For example, the CIPP liner 100 is lowered into the wellbore 10 from the top 10a of the wellbore 10. In some embodiments, a counterweight or cable (not shown) is attached to one end of the CIPP liner to pull the CIPP liner down into the wellbore. For example, this end of the CIPP liner may be attached to one end of a wireline column (not shown) immersed in the well. Alternatively, this end of the CIPP liner may be attached to a retrievable robot (not shown) that remains in the wellbore during expansion and curing. After the CIPP liner has expanded and cured in situ, the retrievable robot can be withdrawn. When the CIPP liner 100 is in a flexible and contracted state, it extends downwards within the wellbore 10 by a predetermined length. This predetermined length may be the length of the wellbore 10 that needs to be lined.

[0031] like Figure 2As shown, when the CIPP liner 100 is located within the wellbore 10, the CIPP liner 100 presses against the wall 11 of the wellbore 10. For example, a fluid (e.g., water) or gas (compressed air) can be pumped into the CIPP liner 100 to cause it to expand. In the expanded state, the CIPP liner 100 will expand radially outward toward the wall 11 of the wellbore 10. The fluid or gas will continue to be pumped into the CIPP liner 100 until it is pressed against the wall 11 of the wellbore 10. Since the diameter of the wellbore 10 is known, a predetermined volume of fluid or gas pumped into the CIPP liner 100 corresponds to the volume that causes the CIPP liner 100 to fully expand against the wall 11 of the wellbore 10. In some embodiments, an internal hose (not shown) can be used to expand the CIPP liner 100 within the wellbore 10. Furthermore, the internal hose can be used to hold the CIPP liner 100 against the wellbore 10 under pressure until it solidifies. In addition, fiber optic cables 101 to 103 can also be used to confirm that the CIPP liner 100 has changed from a contracted state to an expanded state and is fully abutting against the wall 11 of the wellbore 10.

[0032] Once the CIPP liner 100 is abutted against the wall 11 of the shaft 10, the CIPP liner 100 undergoes a chemical process called curing to harden it into a rigid liner and couple the fiber optic cables 101 to 103 to the shaft 10. For example, the resin inside the tube 100a is heated to cure and harden the tube 100a. Further, it is envisioned that since the shaft opening is in a ventilated or outdoor environment, the fumes generated from heating the resin will not accumulate, thus preventing workers from being exposed to the resin material plume. Various curing methods can be used to heat the resin. For example, hot water, steam, or ultraviolet light can be used to raise the temperature of the CIPP liner 100 for the curing process. In some embodiments, the fluid or gas used to expand the CIPP liner 100 can be heated to initiate and complete the curing process. When using ultraviolet light to heat the resin, an ultraviolet lamp is drawn across the CIPP liner 100 to heat the resin. Alternatively, room temperature curing can be used, allowing the CIPP liner 100 to self-cur, depending on the type of resin used that begins to cure once mixed. However, during room temperature curing operations, the CIPP liner 100 must be installed promptly to prevent it from hardening before contacting the wellbore 10.

[0033] In one or more embodiments, fiber optic cables 101 to 103 are used to monitor the curing process. To monitor the curing process, at least one of the fiber optic cables 101 to 103 may be configured in DTS mode to monitor the temperature within the CIPP liner 100 during curing. For example, a second fiber optic cable 102 may be configured in DTS mode to continuously monitor the temperature along the entire length of the CIPP liner 100. In DTS mode, the second fiber optic cable 102 continuously monitors the temperature during curing to confirm more complete curing along the entire length of the CIPP liner 100. Furthermore, at least one of the fiber optic cables 101 to 103 may be configured in DAS mode to monitor the coupling between the CIPP liner 100 and the wellbore 10. For example, the first fiber optic cable 101 and the third fiber optic cable 103 may be configured in DAS mode to continuously monitor vibrations along the entire length of the CIPP liner 100. In DAS mode, the first fiber optic cable 101 and the third fiber optic cable 103 can confirm whether there is sufficient coupling between the CIPP liner 100 and the wall 11 of the wellbore 10. Furthermore, the curing process will attach fiber optic cables 101 to 103 to the wellbore 10 to avoid static strain and tension from the CIPP liner 100. In some embodiments, once attached to the wellbore 10, the fiber optic cables 101 to 103 can be calibrated against static strain and tension from the CIPP liner 100. In general, the fiber optic cables 101 to 103 can be used to monitor various parameters, such as seismic, strain, and temperature measurements, during the installation and curing of the CIPP liner 100. This results in a fully cured, leak-free CIPP liner 100 coupled to the wellbore 100. It is also envisioned that, after the CIPP liner 100 is coupled to the wellbore 100, the fiber optic cables 101 to 103 can also be used to record data during wellbore operations, such as drilling, completion, and any other downhole operations.

[0034] Now refer to Figure 3 The figure shows the installation. Figure 1 and Figure 2 The flowchart shows the method for making CIPP liner 100. Figure 3 One or more steps in the process can be performed by one or more components (e.g., a computing system coupled to a controller communicating with the CIPP liner 100). For example, a non-transitory computer-readable medium can store instructions on memory coupled to a processor, such that these instructions include functions for installing the CIPP liner 100. Although Figure 3 The boxes in the diagram are presented and described in sequence, but those skilled in the art will understand that some or all of the steps may be performed in a different order, may be combined or omitted; and some or all of the steps may be performed in parallel. Furthermore, these steps may be performed actively or passively.

[0035] In step 300, the fiber optic cable is embedded in the CIPP liner. For example, the fiber optic cable can be attached to or braided into a tube within the CIPP liner. During the tube impregnation process, the tube is impregnated with resin, which also embeds the fiber optic cable into the tube. In some embodiments, the fiber optic cable may first be attached to a padding layer, and then the padding layer is attached to the tube. Similarly, once the tube is resin impregnated, the padding layer is secured to the tube.

[0036] Furthermore, fiber optic cables can be attached to or braided into the tube in various orientations as they descend downwards. For example, the first fiber optic cable can be arranged in an inner lining orientation, such that it extends axially downwards along the length of the tube as a relatively straight line. The second fiber optic cable can be arranged in an oscillating orientation, such that it extends downwards along the length of the tube as a sinusoidal line. The third fiber optic cable can be arranged in a random orientation, such that it can extend downwards along the length of the tube in various directions and shapes. For example, the third fiber optic cable can be arranged to have various loops, curves, and straight lines downwards along the length of the tube.

[0037] In step 301, the CIPP liner is lowered into the wellbore. For example, a counterweight or cable is attached to one end of the CIPP liner to pull it down into the wellbore. The CIPP liner extends downwards within the wellbore for a predetermined length. This predetermined length may be the length of the wellbore that requires lining. Furthermore, when the CIPP liner is lowered into the wellbore, it is in a flexible and contracted state. Additionally, while the CIPP liner is inside the wellbore, the tip of a fiber optic cable can be connected to a fiber optic demodulator on the ground above the wellbore.

[0038] In step 302, the CIPP liner is expanded to press against the wellbore. For example, a fluid (e.g., water) or gas (compressed air) may be pumped into the CIPP liner to cause it to expand. As the CIPP liner expands, it expands radially outward toward the wellbore wall. A predetermined volume of fluid or gas is pumped into the CIPP liner until it is pressed against the wellbore wall. The predetermined volume of fluid or gas may correspond to the volume required to expand the CIPP liner to fully press against the wellbore wall. Furthermore, to confirm that the CIPP liner is fully pressed against the wellbore wall, fiber optic cables may be used. For example, the fiber optic cables may be configured in distributed acoustic sensing (DAS) mode to monitor seismic changes and strain occurring on the CIPP liner. If the seismic changes and strain reach a predetermined threshold, the CIPP liner is fully pressed against the wellbore wall. However, if the seismic changes and strain do not reach the predetermined threshold, an alarm may be triggered to continue pumping fluid or gas until the predetermined threshold is reached.

[0039] In step 303, when the CIPP liner is pressed against the wellbore wall, the CIPP liner is cured to harden it into a rigid liner. For example, the resin inside the CIPP liner tube is heated to harden the tube into a rigid tube. Various curing methods can be used to heat the resin. For example, hot water, steam, or ultraviolet light can be used to raise the temperature of the CIPP liner to cure the resin. In some embodiments, the fluid or gas used to expand the CIPP liner can be heated to initiate and complete the curing process.

[0040] In step 304, during the curing process, fiber optic cables monitor the curing of the CIPP liner. For example, at least one fiber optic cable is configured in distributed temperature sensing (DTS) mode to monitor temperature during curing. In DTS mode, the at least one fiber optic cable continuously monitors the temperature along the entire length of the CIPP liner. Based on the recorded temperatures, the at least one fiber optic cable can confirm more complete curing along the entire length of the CIPP liner. For example, if the recorded temperature reaches a predetermined temperature threshold within a predetermined time, the CIPP liner has been fully cured to transform the CIPP liner into a rigid tube. The predetermined temperature threshold is the temperature required to initiate the curing process (e.g., heating the resin to carry out a chemical reaction). Furthermore, the predetermined time is the period of time during which the resin must be heated at the predetermined temperature threshold to fully cure the CIPP liner. However, if the recorded temperature does not reach the predetermined temperature threshold, an alarm can be triggered to continue heating the resin until the predetermined temperature threshold is reached. It is also envisioned that after the predetermined time, the at least one fiber optic cable can be used to record temperatures to confirm that the CIPP liner has hardened. For example, if the recorded temperature after a predetermined time does not reach the predetermined temperature for curing the CIPP liner, an alarm can be issued to continue heating the resin until the predetermined temperature is reached.

[0041] In step 305, once the CIPP liner has cured, it is coupled to the wellbore. For example, as the resin cures, the CIPP liner adheres to the wellbore wall. This also allows the fiber optic cable to be coupled to the wellbore. Furthermore, at least one fiber optic cable can be configured in DAS mode to monitor the coupling between the CIPP liner and the wellbore. For example, the at least one fiber optic cable continuously monitors vibration and strain along the entire length of the CIPP liner to confirm adequate coupling between the CIPP liner and the wellbore wall.

[0042] In step 306, with the CIPP liner coupled to the wellbore, the fiber optic cable continuously monitors the wellbore. For example, the fiber optic cable records well data during wellbore operations (such as drilling, completion, and any other downhole operations).

[0043] Now refer to Figures 4 to 7 In one or more embodiments, Figures 4 to 7The use of well site 400 is shown. Figure 1 and Figure 2 CIPP liner 100 implementation Figure 3 The flowchart describes the system of methods.

[0044] Turning Figure 4 In one or more embodiments, an example of a well site 400 is shown. A wellbore 410 is formed by drilling from the surface 414 into formation 412. First, the wellbore 410 is drilled into formation 412 to a first depth D1. This first depth D1 may correspond to a shallow section of the wellbore 410 drilled in the unconsolidated formation 412a of formation 412. To support the wellbore 410 in the unconsolidated formation 412a of formation 412, a casing string is typically installed and secured to the wellbore 410. However, before installing the casing string, a CIPP liner 100 is first installed in the wellbore 410.

[0045] In one or more embodiments, the CIPP liner 100 is inserted into the wellbore 410. For example, a liner reel 405 unwinds the CIPP liner 100 into a wellhead 418 located at the top of the wellbore 410 at the ground surface 414. Starting from the wellhead 418, the CIPP liner 100 is lowered into the wellbore 410. Initially, the CIPP liner 100 is in a retracted state to facilitate insertion into the wellbore 410.

[0046] like Figure 5 As shown, once the CIPP liner 100 is lowered into the wellbore to a length equal to the first depth D1, the portions 101a to 103a of each fiber optic cable 101 to 103 that are not inside the wellbore 410 are connected to the fiber optic demodulator 101a to 103a at the surface 414. Additionally, a pump 406 is attached to the wellhead 418 to expand the CIPP liner 100.

[0047] Turning Figure 6 The CIPP liner 100 is expanded to press against the wellbore 410. For example, pump 406 pumps fluid (e.g., water) or gas (compressed air) into the CIPP liner 100 to cause it to expand. In the expanded state, the CIPP liner 100 expands radially outward toward the wellbore 410. Fluid or gas will continue to be pumped into the CIPP liner 100 until it is pressed against the wellbore 410. Furthermore, fiber optic cables 101 to 103 can be used to confirm that the CIPP liner 100 has transitioned from a contracted state to an expanded state and is fully pressed against the wellbore 410. For example, at least one of the fiber optic cables 101 to 103 can be switched to DAS mode to measure vibrations corresponding to contact with the wellbore 410.

[0048] Once the CIPP liner 100 is pressed against the wellbore 410, the CIPP liner 100 is cured. For example, a heater 407 coupled to the wellhead 418 heats the resin within the CIPP liner 100 to harden the CIPP liner 100 into a rigid tube. In some embodiments, the heater 407 may heat fluid or gas from a pump 406 to initiate and complete the curing process. Alternatively, the heater 407 may be an ultraviolet lamp pulled across the CIPP liner 100 to heat the resin. As described above, fiber optic cables 101 to 103 are used to monitor the curing process. Once the CIPP liner 100 is cured, the CIPP liner 100 is coupled to the wellbore 410. For example, the CIPP liner 100 becomes a rigid tube attached to the wellbore 410.

[0049] like Figure 7 As shown, with the CIPP liner 100 coupled to the wellbore 410, a casing string 415 is run into the wellbore 410. The casing string 415 can be a large-diameter casing used to protect shallow formations from drilling fluid contamination and to help prevent scouring or collapse of unconsolidated topsoil and sediments involved in unconsolidated formation 412a. Furthermore, cementing operations are performed on the casing string 415. For example, cement grout is used to cement the casing string 415 onto the CIPP liner 100. Fiber optic cables 101 to 103 within the CIPP liner 100 are also envisioned for use in monitoring the cementing operations on the casing string 415. After the casing string 415 is cemented, drilling operations can be performed to further penetrate the wellbore 410 into the formation 412 to reach the reservoir.

[0050] Now refer to Figures 8 to 10 The figure shows another embodiment of installing the CIPP liner 100 at the well site 400 according to an embodiment of this specification, wherein similar characters indicate similar parts. Figures 8 to 10 Implementation examples and Figures 4 to 6 The embodiments are similar. However, instead of installing the CIPP liner 100 first, the casing string 415 can be run in first and consolidated against the wellbore 410. After the casing string 415 is consolidated, the CIPP liner 100 is run into the wellbore 410 and expanded to abut against the casing string 415.

[0051] Now refer to Figure 11 and Figure 12 The figure shows another embodiment of the CIPP liner according to the embodiments of this specification, wherein similar characters denote similar parts. Figure 11 and Figure 12 Implementation examples and Figure 1 and Figure 2The embodiments are similar. However, instead of inflating the CIPP liner 100, the CIPP liner 1100 is installed in the wellbore 10 by inversion. During the inversion process, the CIPP liner 1100 is forced to invert and rotate along the wall 11 of the wellbore 10 by a fluid (e.g., water) or a gas (e.g., compressed air). For example, the CIPP liner 1100 is inverted such that the inverted CIPP liner 1100 self-unfolds along the wall 11 of the wellbore 10.

[0052] like Figure 11 As shown, the end face 1100b of the tube 1100a of the inverted CIPP liner 1100 is coupled to a clamp 1106 on the top 10a of the wellbore 10. From the clamp 1106, a fluid (e.g., water) or gas (e.g., compressed air) is pumped into the inverted CIPP liner 1100, causing the inner layer 1107 of the tube 1100a to become the outer layer 1108 of the tube 1100a. Furthermore, the inverted CIPP liner 1100 may have a treatment / sealing layer impregnated on the outside of the tube 1100a. For example, when the inverted CIPP liner 1100 is in the inverted state, the treatment / sealing layer becomes the inner surface of the inverted CIPP liner 1100. Additionally, uncured resin can then flow into cracks and openings in the wall 11 of the wellbore 10 to lock the inverted CIPP liner 1100 in place before curing. In one or more embodiments, at clamp 1106, the fiber optic cables embedded in the flipped CIPP liner 1100 each have portions 101a to 103a that are not inside the wellbore 10.

[0053] and Figure 2 similar, Figure 12 The image shows the inverted CIPP liner 1100 pressed against the wellbore 10. For example, once a fluid (e.g., water) or gas (e.g., compressed air) has completed the full-length inversion of the inverted CIPP liner 1100, the outer layer 1108 of the tube 1100a will press against the wellbore wall. Once the inverted CIPP liner 1100 has been fully inverted and is pressed against the wall 11 of the wellbore 10, the inverted CIPP liner 1100 will then be cured.

[0054] Now refer to Figure 13 The figure shows the installation. Figure 11 and Figure 12 A flowchart of the method for flipping the CIPP liner 1100. Figure 13 One or more steps in the process can be performed by one or more components (e.g., a computing system coupled to a controller communicating with the inverted CIPP liner 1100). For example, a non-transitory computer-readable medium can store instructions on a memory coupled to a processor, such that these instructions include functionality for installing the inverted CIPP liner 1100. Although Figure 13The boxes in the diagram are presented and described in sequence, but those skilled in the art will understand that some or all of the steps may be performed in a different order, may be combined or omitted; and some or all of the steps may be performed in parallel. Furthermore, these steps may be performed actively or passively.

[0055] In step 1300, the fiber optic cable is embedded in the CIPP liner. For example, the fiber optic cable can be attached to or braided into the inner layer of the CIPP liner tube. During the tube impregnation process, the tube is impregnated with resin, which also embeds the fiber optic cable into the tube. In some embodiments, the fiber optic cable may first be attached to a pad, and then the pad is attached to the inner layer of the tube. Similarly, once the tube is resin impregnated, the pad is secured to the tube.

[0056] Furthermore, fiber optic cables can be attached to or braided into the tube in various orientations as it descends along the tube. For example, the first fiber optic cable can be arranged in an inner lining orientation, such that it extends axially downwards along the length of the tube as a relatively straight line. The second fiber optic cable can be arranged in an oscillating orientation, such that it extends downwards along the length of the tube as a sinusoidal line. The third fiber optic cable can be arranged in a random orientation, such that it can extend downwards along the length of the tube in various directions and shapes. For example, the third fiber optic cable can be arranged to have various loops, curves, and straight lines downwards along the length of the tube.

[0057] In step 1301, the CIPP liner is flipped into the wellbore. For example, one end of the CIPP liner is coupled to a clamp above the wellbore, and then the CIPP liner is flipped inside out. Furthermore, to complete the flipping of the CIPP liner, a fluid (e.g., water) or gas (e.g., compressed air) is pumped into the CIPP liner, causing the inner layer of the CIPP liner to become the outer layer. A predetermined volume of fluid or gas continues to be pumped until the flipped CIPP liner has fully expanded along the wellbore wall. The predetermined volume of fluid or gas may correspond to the volume required to flip the CIPP liner until it is completely pressed against the wellbore wall. Furthermore, to confirm that the CIPP liner has been fully flipped and is fully pressed against the wellbore wall, a fiber optic cable can be used. For example, the fiber optic cable can be configured in distributed acoustic sensing (DAS) mode to monitor seismic changes and strain occurring on the flipped CIPP liner. If the seismic changes and strain reach a predetermined threshold, the flipped CIPP liner is considered to be fully pressed against the wellbore wall. However, if the seismic changes and strain do not reach the predetermined threshold, an alarm can be issued to continue pumping fluid or gas until the predetermined threshold is reached.

[0058] In step 1302, when the inverted CIPP liner is pressed against the wellbore wall, the inverted CIPP liner is cured to harden it into a rigid liner. For example, the resin inside the inverted CIPP liner tube is heated to harden the tube into a rigid tube. Various curing methods can be used to heat the resin. For example, hot water, steam, or ultraviolet light can be used to raise the temperature of the inverted CIPP liner to cure the resin. In some embodiments, the fluid or gas used to invert the CIPP liner can be heated to initiate and complete the curing process.

[0059] In step 1303, during the curing process, fiber optic cables monitor the curing of the inverted CIPP liner. For example, at least one fiber optic cable is configured in distributed temperature sensing (DTS) mode to monitor temperature during curing. In DTS mode, the at least one fiber optic cable continuously monitors the temperature along the entire length of the inverted CIPP liner. Based on the recorded temperatures, the at least one fiber optic cable can confirm more complete curing along the entire length of the inverted CIPP liner. For example, if the recorded temperature reaches a predetermined temperature threshold within a predetermined time, the inverted CIPP liner has been fully cured to transform the inverted CIPP liner into a rigid tube. The predetermined temperature threshold is the temperature required to initiate the curing process (e.g., heating the resin to carry out a chemical reaction). Furthermore, the predetermined time is the period of time during which the resin must be heated at the predetermined temperature threshold to fully cure the inverted CIPP liner. However, if the recorded temperature does not reach the predetermined temperature threshold, an alarm can be issued to continue heating the resin until the predetermined temperature threshold is reached. It is also envisioned that after the predetermined time, the at least one fiber optic cable can be used to record temperatures to confirm that the inverted CIPP liner has hardened. For example, if the recorded temperature after a predetermined time does not reach the predetermined temperature of the hardened, inverted CIPP liner, an alarm can be triggered to continue heating the resin until the predetermined temperature is reached.

[0060] In step 1304, once the inverted CIPP liner has cured, it is coupled to the wellbore. For example, as the resin cures, the inverted CIPP liner adheres to the wellbore wall. This also allows the fiber optic cable to be coupled to the wellbore. Furthermore, at least one fiber optic cable can be configured in DAS mode to monitor the coupling between the inverted CIPP liner and the wellbore. For example, the at least one fiber optic cable continuously monitors vibration and strain along the entire length of the inverted CIPP liner to confirm adequate coupling between the inverted CIPP liner and the wellbore wall.

[0061] In step 1305, with the inverted CIPP liner coupled to the wellbore, the fiber optic cable continuously monitors the wellbore. For example, the fiber optic cable records well data during wellbore operations such as drilling, completion, and any other downhole operations.

[0062] Now refer to Figures 14 to 16 In one or more embodiments, Figures 14 to 16 The use of well site 1400 is shown. Figure 11 and Figure 12 CIPP liner 1100 implementation Figure 13 The flowchart describes the system of methods.

[0063] Turning Figure 14 In one or more embodiments, an example of a well site 1400 is shown. A wellbore 1410 is formed by drilling from the surface 1414 into formation 1412. First, the wellbore 1410 is drilled into formation 1412 to a first depth D1. This first depth D1 may correspond to a shallow section of the wellbore 1410 drilled in the unconsolidated formation 1412a of formation 1412. To support the wellbore 1410 in the unconsolidated formation 1412a of formation 1412, a casing string is typically installed and secured to the wellbore 1410. However, before installing the casing string, a CIPP liner 1100 is first installed in the wellbore 1410.

[0064] In one or more embodiments, the CIPP liner 1100 is inserted into the wellbore 1410 by flipping. For example, a liner reel 1405 unwinds the CIPP liner 1100 into a wellhead 1418 mounted on top of the wellbore 1410 at the surface 1414. In the wellhead 1418, the end faces of the CIPP liner 1100 are coupled to a clamp. By coupling the end faces of the CIPP liner 1100 to the clamp in the wellhead 1418, the CIPP liner 1100 is flipped inside out. Next, a pump 1406 attached to the wellhead 1418 pumps fluid (e.g., water) or gas (compressed air) into the CIPP liner 1100 to force the inner layer 1107 of the CIPP liner 1100 to become the outer layer 1108 of the CIPP liner 1100.

[0065] Turning Figure 15 Once the CIPP liner 1100 is fully flipped, the entire length of the outer layer 1108 of the CIPP liner 1100 presses against the wellbore 1410. Furthermore, fiber optic cables 101 to 103 can also be used to confirm that the CIPP liner 1100 has been fully flipped and is fully pressed against the wellbore 1410. For example, at least one of the fiber optic cables 101 to 103 can be switched to DAS mode to measure vibrations corresponding to contact with the wellbore 1410.

[0066] Once the inverted CIPP liner 1100 is pressed against the wellbore 1410, the inverted CIPP liner 1100 is cured. For example, a heater 1407 coupled to the wellhead 1418 heats the resin within the inverted CIPP liner 1100 to harden the inverted CIPP liner 1100 into a rigid tube. In some embodiments, the heater 1407 may heat fluid or gas from a pump 1406 to initiate and complete the curing process. Alternatively, the heater 1407 may be an ultraviolet lamp that is pulled across the inverted CIPP liner 1100 to heat the resin. As described above, fiber optic cables 101 to 103 are used to monitor the curing process. Once the inverted CIPP liner 1100 is cured, it is coupled to the wellbore 1410. For example, the inverted CIPP liner 1100 becomes a rigid tube attached to the wellbore 1410.

[0067] like Figure 16 As shown, with the overturned CIPP liner 1100 coupled to the wellbore 1410, a casing string 1415 is run into the wellbore 1410. The casing string 1415 can be a large-diameter casing used to protect shallow formations from drilling fluid contamination and to help prevent scouring or collapse of unconsolidated topsoil and sediments involved in unconsolidated formation 1412a. Furthermore, the casing string 1415 is cemented. For example, cement slurry is used to cement the casing string 1415 onto the overturned CIPP liner 1100. It is also envisioned that fiber optic cables 101 to 103 in the overturned CIPP liner 1100 can be used to monitor the cementing operation of the casing string 1415. After the casing string 1415 is cemented, drilling operations can be performed to further penetrate the wellbore 1410 into formation 1412 to reach the reservoir.

[0068] Now refer to Figure 17 and Figure 18 The figure shows another embodiment of installing CIPP liner 1100 at well site 1400 according to an embodiment of this specification, wherein similar characters indicate similar parts. Figure 17 and Figure 18 Implementation examples and Figure 14 and Figure 15 The embodiments are similar. However, instead of installing the CIPP liner 1100 first, the casing string 1415 can be run in first and consolidated against the wellbore 1410. After the casing string 1415 is consolidated, the CIPP liner 1100 is flipped into the wellbore 1410 until it rests against the casing string 1415.

[0069] The implementation methods for operating wellbore work and fiber optic cables described in this specification can be implemented on a computing system coupled to a controller that communicates with the various components of the CIPP liner. Figure 19This is a block diagram of a computer system 1902 according to one embodiment, which provides computational capabilities associated with the algorithms, methods, functions, processes, flows, and programs described in this disclosure. The illustrated computer 1902 is intended to encompass any computing device, such as a high-performance computing (HPC) device, server, desktop computer, laptop / notebook computer, wireless data port, smartphone, personal digital assistant (PDA), tablet computing device, one or more processors from these devices, or any other suitable processing device, including physical or virtual instances (or both) of computing devices. Furthermore, the computer 1902 may include a computer containing input devices (e.g., a keypad, keyboard, touchscreen, or other devices capable of accepting user information) and output devices or a GUI that convey information (including digital data, visual or audio information (or combinations thereof)) associated with the operation of the computer 1902.

[0070] Computer 1902 may act as a client, network component, server, database or other persistent device, or any other component (or combination of roles) of a computer system performing the subject matter described herein. The illustrated computer 1902 is communicatively coupled to network 1930. In some embodiments, one or more components of computer 1902 may be configured to operate in an environment including a cloud-based environment, a local environment, a global environment, or other environments (or combinations thereof).

[0071] At a higher level, computer 1902 is an electronic computing device operable to receive, transmit, process, store, or manage data and information associated with the subject matter. According to some embodiments, computer 1902 may also include, or be communicatively coupled to, an application server, email server, web server, cache server, streaming data server, business intelligence (BI) server, or other server (or combination of servers).

[0072] Computer 1902 can receive requests from client applications (e.g., executed on another computer 1902) via network 1930 and respond to the requests by processing the received requests in appropriate software applications. Additionally, requests can also be sent to computer 1902 from internal users (e.g., from a console or via other appropriate access methods), external or third parties, other automated applications, and any other appropriate entity, individual, system, or computer.

[0073] Each component of computer 1902 can communicate using system bus 1903. In some implementations, any or all components of computer 1902, whether hardware or software (or a combination of hardware and software), can interface with each other or with interface 1904 (or a combination of both) via system bus 1903 using application programming interface (API) 1912 or service layer 1913 (or a combination of API 1912 and service layer 1913). API 1912 may include specifications for routines, data structures, and object classes. API 1912 may be independent of or dependent on a computer language and may refer to a complete interface, a single function, or even a set of APIs. Service layer 1913 provides software services to computer 1902 or other components (whether shown or not) communicatively coupled to computer 1902. Using this service layer, all service consumers can access the functionality of computer 1902. Software services (such as those provided by service layer 1913) provide reusable, defined business functions through defined interfaces. For example, the interface may be software written in JAVA, C++, or other suitable languages, providing data in Extensible Markup Language (XML) format or other suitable formats. Although shown as an integrated component of computer 1902, alternative implementations may show API 1912 or service layer 1913 as a separate component relative to or communicatively coupled to other components of computer 1902 (whether shown or not). Furthermore, any or all portions of API 1912 or service layer 1913 may be implemented as a submodule or sub-module of another software module, enterprise application, or hardware module without departing from the scope of this disclosure.

[0074] Computer 1902 includes interface 1904. Although Figure 19 A single interface 1904 is shown, but two or more interfaces 1904 may be used depending on the specific needs, expectations, or implementation of computer 1902. Computer 1902 uses interface 1904 to communicate with other systems connected to network 1930 in a distributed environment. Typically, interface 1904 includes logic encoded in software or hardware (or a combination of software and hardware) and operable to communicate with network 1930. More specifically, interface 1904 may include software supporting one or more communication protocols associated with the communication, enabling network 1930 or interface hardware to operate to transmit physical signals both inside and outside the illustrated computer 1902.

[0075] Computer 1902 includes at least one computer processor 1905. Although Figure 19The computer 1905 is shown as a single computer processor 1905, but two or more processors may be used depending on the specific needs, expectations, or particular implementation of the computer 1902. Typically, the computer processor 1905 executes instructions and manipulates data to perform the operations of the computer 1902 and any algorithms, methods, functions, processes, flows, and programs described in this disclosure.

[0076] Computer 1902 also includes memory 1906, which stores data from computer 1902 or other components (or a combination of both) that can be connected to network 1930. For example, memory 1906 may be a database storing data consistent with this disclosure. Although Figure 19 The memory 1906 is shown as a single memory unit, but two or more memories may be used depending on the specific needs, expectations, or particular implementation of the computer 1902 and the functions described. Although the memory 1906 is shown as an integrated component of the computer 1902, in alternative embodiments, the memory 1906 may be external to the computer 1902.

[0077] Application 1907 is an algorithmic software engine that provides functionality based on the specific needs, expectations, or specific implementation of computer 1902, particularly with respect to the functionality described in this disclosure. For example, application 1907 may act as one or more components, modules, applications, etc. Furthermore, although shown as a single application 1907, application 1907 may be implemented as multiple applications 1907 on computer 1902. Additionally, although shown as integrated into computer 1902, in alternative embodiments, application 1907 may be external to computer 1902.

[0078] Any number of computers 1902 may be associated with or outside the computer system containing the computers 1902, each computer 1902 communicating via the network 1930. Furthermore, the terms "client," "user," and other appropriate terms may be used interchangeably where appropriate without departing from the scope of this disclosure. Moreover, this disclosure contemplates that many users may use one computer 1902, or that one user may use multiple computers 1902.

[0079] In some embodiments, computer 1902 is implemented as part of a cloud computing system. For example, a cloud computing system may include one or more remote servers and various other cloud components, such as cloud storage units and edge servers. Specifically, the cloud computing system can perform one or more computing operations without direct, active management by user devices or local computer systems. Therefore, a cloud computing system can have different functions distributed across multiple locations from a central server, which can be performed using one or more internet connections. More specifically, the cloud computing system can operate according to one or more service models, such as Infrastructure as a Service (IaaS), Platform as a Service (PaaS), Software as a Service (SaaS), Mobile “Backend” as a Service (MBaaS), Serverless Computing, Artificial Intelligence as a Service (AIaaS), and / or Function as a Service (FaaS).

[0080] In addition to the benefits mentioned above, CIPP liners with fiber optic cables can improve the overall efficiency and performance of the well, while reducing costs, improving field safety, reducing non-productive time (NPT) risks, and offering many other advantages. Furthermore, CIPP liners with fiber optic cables can provide other benefits such as continuous in-well DAS and DTS, real-time, efficient, and effective well data measurement along the entire length of the CIPP liner, and reduced or eliminated human interaction with the well, thereby reducing human error.

[0081] While the invention has been described with respect to a limited number of embodiments, those skilled in the art, who will benefit from this disclosure, will understand that other embodiments can be devised without departing from the scope of the invention disclosed herein. Therefore, the scope of the invention should be limited only by the appended claims.

Claims

1. A method for lining a wellbore (10, 410), the method comprising: The in-situ cured pipe liner (100) is inserted into the well shaft (10, 410); This forces the in-situ cured pipe liner (100) to abut against the wall (11) of the well shaft. Curing of the in-situ cured pipe lining (100); The curing of the in-situ cured pipe liner (100) is monitored using one or more optical fiber cables (101, 102, 103) embedded in the in-situ cured pipe liner (100); The in-situ cured pipe liner (100) is coupled to the wall (11) of the wellbore; and The wellbore (10, 410) is continuously monitored using one or more optical fiber cables (101, 102, 103).

2. The method according to claim 1, wherein, Inserting the in-situ cured pipe liner (100) into the well shaft (10, 410) also includes: The in-situ cured pipe liner (100) is lowered into the well shaft (10, 410) in a contracted state.

3. The method according to claim 2, wherein, Forcing the in-situ cured pipe liner (100) against the wall (11) of the well shaft also includes: Pump fluid or gas into the in-situ cured pipe lining (100); The in-situ cured pipe liner (100) expands to expand radially outward toward the wall (11) of the wellbore; and The in-situ cured pipe lining (100) is in an expanded state and abuts against the wall (11) of the well.

4. The method according to claim 3, further comprising: At least one of the one or more optical fiber cables (101, 102, 103) is configured in a distributed acoustic sensing mode; and Vibrations in the in-situ cured pipe liner (100) are recorded to confirm that the in-situ cured pipe liner abuts against the wall (11) of the wellbore.

5. The method according to claim 4, wherein, If the recorded vibration does not reach a predetermined threshold, the method further includes: An alarm is issued to continue pumping the fluid or gas until the predetermined threshold is reached.

6. The method according to any one of claims 1 to 5, wherein, Monitoring the curing of the in-situ cured pipe lining (100) using one or more fiber optic cables (101, 102, 103) also includes: At least one of the one or more optical fiber cables (101, 102, 103) is configured as a distributed temperature sensing mode; and Record the temperature of the resin in the in-situ cured pipe liner (100) to confirm that the in-situ cured pipe liner (100) has been cured and formed a rigid pipe coupled to the wall (11) of the well shaft.

7. The method according to claim 6, wherein, If the recorded temperature does not reach a predetermined temperature threshold within a predetermined time, the method further includes: An alarm is issued to continue heating the resin until the predetermined temperature threshold is reached so that the in-situ cured pipe liner (100) is fully cured.

8. The method according to any one of claims 1 to 7, further comprising: The casing string (415) is lowered into the wellbore (410); and The casing (415) is fixed against the in-situ cured pipe liner (100).

9. A method for lining a wellbore (10, 1410), the method comprising: The in-situ cured pipe lining (1100) is flipped over and enters the well shaft (10, 1410). This forces the in-situ cured pipe liner (1100) to abut against the wall (11) of the well shaft. Curing of the in-situ cured pipe lining (1100); The curing of the in-situ cured pipe liner (1100) is monitored using one or more optical fiber cables (101, 102, 103) embedded in the in-situ cured pipe liner (1100); The in-situ cured pipe liner (1100) is coupled to the wall (11) of the wellbore; and The wellbore (10, 1410) is continuously monitored using one or more optical fiber cables (101, 102, 103).

10. The method according to claim 9, wherein, The process of turning over the in-situ cured pipe lining (1100) into the shaft (10, 1410) also includes: The in-situ cured pipe liner (1100) is flipped inside out.

11. The method according to claim 9 or 10, further comprising: One end of the in-situ cured pipe liner (1100) is coupled to a clamp (1106) above the wellbore (10, 1410).

12. The method according to any one of claims 9 to 11, wherein, The process of bringing the in-situ cured pipe liner (1100) against the wall (11) of the well shaft further includes: Pump fluid or gas into the in-situ cured pipe lining (1100); This forces the inner layer (1107) of the in-situ cured pipe liner to become the outer layer (1108) of the in-situ cured pipe liner; and The outer layer (1108) of the in-situ cured pipe lining is brought against the wall (11) of the well shaft.

13. The method of claim 12, further comprising: At least one of the one or more optical fiber cables (101, 102, 103) is configured in a distributed acoustic sensing mode; and Vibrations in the in-situ cured pipe liner (100) are recorded to confirm that the outer layer (1108) of the in-situ cured pipe liner abuts against the wall (11) of the wellbore.

14. The method according to claim 13, wherein, If the recorded vibration does not reach a predetermined threshold, the method further includes: An alarm is issued to continue pumping the fluid or gas until the predetermined threshold is reached.

15. The method according to any one of claims 9 to 14, wherein, Monitoring the curing of the in-situ cured pipe lining (1100) using one or more fiber optic cables (101, 102, 103) also includes: At least one of the one or more optical fiber cables (101, 102, 103) is configured as a distributed temperature sensing mode; and Record the temperature of the resin in the in-situ cured pipe liner to confirm that the in-situ cured pipe liner (1100) has been cured and formed a rigid pipe coupled to the wall (11) of the well shaft.

16. The method according to claim 15, wherein, If the recorded temperature does not reach a predetermined temperature threshold within a predetermined time, the method further includes: An alarm is issued to continue heating the resin until the predetermined temperature threshold is reached so that the in-situ cured pipe liner (1100) is fully cured.

17. The method according to any one of claims 9 to 16, further comprising: The casing string (1415) is lowered into the wellbore (1410); and The casing string (1415) is fixed against the in-situ cured pipe lining (1100).

18. A system comprising: The wellbore (10, 410, 1410) extends to the first depth (D1) within the formation. In-situ cured pipe liners (100, 1100), which are coupled to the wall of the wellbore; and One or more optical fiber cables (101, 102, 103) are embedded in the in-situ cured pipe lining (100, 1100) for monitoring the curing of the in-situ cured pipe lining and recording well data. The one or more fiber optic cables (101, 102, 103) are used for continuous monitoring of the wellbore (10, 410, 1410) during the process of lining the wellbore, the method comprising: Insert the in-situ cured pipe lining (100, 1100) into the well shaft; The in-situ cured pipe lining (100, 1100) is brought against the wall of the well shaft; Curing of the in-situ cured pipe lining (100, 1100); The curing of the in-situ cured pipe lining (100, 1100) is monitored using one or more fiber optic cables (101, 102, 103) embedded in the lining; and The in-situ cured pipe lining (100, 1100) is coupled to the wall of the well.

19. The system according to claim 18, wherein, The first depth (D1) is the shallow section of the wellbore (10, 410, 1410) drilled in the unconsolidated strata of the formation.

20. The system according to claim 18 or 19 further includes a conduit sleeve (415, 1415) fixed to the in-situ cured conduit liner (100, 1110).

Images