Distributed sensing enhancement system and method under wireline load bearing well logging operation system

Abstract

This invention discloses a distributed sensing enhancement system and method for wire rope-supported logging operations, comprising: a winch-optical cable unit, including a winch and an optical cable; a tail-end point sensor unit for acquiring temperature and pressure values ​​at the target well depth; a surface distributed acquisition unit for acquiring single-mode and multi-mode fiber optic data; and a data fusion and calibration unit for obtaining corrected distributed acoustic and temperature data based on the temperature and pressure values ​​at the target well depth, distributed acoustic data, and distributed temperature data. This invention, without altering the traditional wire rope-supported logging operation process or existing engineering system, enhances logging sensing capabilities from single-point acquisition to continuous acquisition along the wellbore, improving the continuity of downhole parameter acquisition and the reliability of engineering interpretation.

Description

Technical Field

[0001] This invention relates to the field of geological logging technology, and in particular to a distributed sensing enhancement system and method for a wire rope-supported logging operation system. Background Technology

[0002] Geological logging is one of the important technical means used in fields such as geological engineering, engineering drilling, scientific drilling, and resource exploration to obtain physical parameters of the wellbore and surrounding formations. Generally speaking, well logging operations involve lowering measuring tools into the wellbore along with the carrying medium to obtain formation or downhole environmental parameters such as temperature and pressure at specific depths to reflect the characteristics and changes in the formation structure.

[0003] In long-term engineering practice, wire ropes have been widely used as the load-bearing medium in well logging operations due to their high strength, good flexibility, and mature operating technology. In wire rope logging, logging sensors are typically installed at the end or a localized location of the wire rope, and are lowered into the wellbore along with the wire rope to complete the measurement task, serving as the basic configuration for acquiring logging data. However, limited by the structural form and load-bearing capacity of the wire rope, logging sensor components are usually only arranged at the end of the wire rope or in a very few fixed locations. This approach has the following drawbacks: On the one hand, downhole parameters can only be obtained at limited depths, and are mainly concentrated at single points at the bottom of the well, making it impossible to form a complete, continuous wellbore profile in a single operation. When it is necessary to analyze the formation's variation trend along depth or identify abnormal sections, supplementary measurements are often only possible through segmented deployment or repeated operations, increasing the complexity of on-site organization.

[0004] On the other hand, if multiple sensing components are added to the wire rope to increase the sampling density, the weight and outer diameter of the rope will be significantly increased, increasing the frictional resistance of the well wall and the risk of jamming. At the same time, higher requirements will be placed on the winch traction capacity and wellhead safety management, thus limiting the feasibility of the project.

[0005] To improve the spatial continuity of downhole parameter acquisition, distributed fiber optic sensing technology has been increasingly applied in wellbore monitoring in recent years. This technology analyzes the scattered signals along the length of the optical fiber, transforming the entire fiber into continuously distributed sensing units. Theoretically, this enables continuous measurement of downhole parameters, significantly improving spatial resolution and information density.

[0006] However, existing distributed fiber optic logging solutions typically rely on dedicated fiber optic cable laying methods or permanent cable installation structures, and are mostly used for long-term monitoring or fixed wellbore deployment scenarios. Their structural form and operating mode differ significantly from traditional wire rope-supported logging. These solutions often require specialized design for the wellbore structure, cable laying path, or surface equipment configuration, making direct compatibility with existing wire rope logging winch systems and field organization methods difficult. When applied to temporary logging, periodic monitoring, or existing wellbore conditions, both engineering adaptability and economic efficiency are limited. Summary of the Invention

[0007] To address the technical problems existing in the background technology, a distributed sensing enhancement system and method under the wire rope bearing logging operation system is proposed.

[0008] In a first aspect, the present invention proposes a distributed sensing enhancement system under a wire rope-supported well logging operation system, comprising: The winch-optical cable unit includes a winch and an optical cable, wherein the optical cable integrates at least one single-mode optical fiber and at least one multimode optical fiber; The tail-end point sensor unit is fixedly installed at the end of the optical cable to obtain temperature and pressure values ​​at the target well depth. The ground-based distributed acquisition unit includes a distributed acoustic sensing system connected to a single-mode fiber and a distributed temperature sensing system connected to a multimode fiber, used to acquire single-mode fiber data and multimode fiber data. The data fusion and calibration unit is used to obtain distributed acoustic data along the length of the optical cable based on single-mode optical fiber data; to obtain distributed temperature data along the length of the optical cable based on multimode optical fiber data; and to obtain corrected distributed acoustic data and distributed temperature data based on the temperature and pressure values ​​at the target well depth, as well as the distributed acoustic data and distributed temperature data.

[0009] Preferably, based on the temperature and pressure values ​​at the target well depth, as well as the distributed acoustic data and distributed temperature data, corrected distributed acoustic data and distributed temperature data are obtained, specifically including: Establish a one-to-one correspondence between the distributed sampling points of the optical cable along its length and the actual well depth; Based on the one-to-one correspondence between the distributed sampling points of the optical cable along its length and the actual well depth, the corresponding sampling positions of the target well depth of the tail point sensor unit in the distributed acoustic data and distributed temperature data are determined. Based on the corresponding sampling positions of the tail point sensor unit in the distributed acoustic data and distributed temperature data, the temperature and pressure values ​​obtained by the tail point sensor unit are used as reference quantities to perform reference correction on the distributed acoustic data and distributed temperature data, resulting in corrected distributed acoustic data and distributed temperature data.

[0010] Preferably, establishing a one-to-one correspondence between the distributed sampling points along the length of the optical cable and the actual well depth specifically includes: When the optical cable is lowered to the target well depth, a disturbance signal is applied to the optical cable at the wellhead, and the corresponding vibration response is recorded using a distributed acoustic sensing system. Local heating is applied to the optical cable at the wellhead, and a distributed temperature sensing system is used to record abnormal temperature responses. Based on the vibration response corresponding to the disturbance signal recorded by the distributed acoustic sensing system, the reference sampling point of the wellhead location in the distributed acoustic data is determined. Based on the temperature anomaly response corresponding to local heating recorded by the distributed temperature sensing system, the reference sampling point of the wellhead location in the distributed temperature data is determined. Based on the reference sampling points of the wellhead location in the distributed acoustic data and the reference sampling points of the wellhead location in the distributed temperature data, a correspondence between the distributed sampling points of the optical cable along its length and the actual well depth is established.

[0011] Preferably, the benchmark correction includes one or more of the following: overall offset correction, linear fitting correction, and nonlinear fitting correction.

[0012] Preferably, after obtaining the corrected distributed acoustic data and distributed temperature data, the method further includes: The system detects whether the temperature and pressure values ​​at the target well depth exhibit abrupt changes, periodic fluctuations, or trends within a certain time period. If so, this time period is used as the effective analysis window. Within this effective analysis window, the distributed acoustic data corresponding to the depth segment of the target well depth is extracted, and the vibration amplitude and spectral characteristics of the distributed acoustic data are analyzed. When distributed acoustic data shows amplitude or spectral characteristic changes consistent with the pressure change trend in the same depth section, the state type of the well section is determined by combining the pressure change direction and amplitude characteristics.

[0013] Preferably, in the process of determining the state type, when the pressure increases and the distributed acoustic data shows a continuously enhanced low-frequency vibration component in the corresponding depth segment, it is determined to be a fluid flow or injection disturbance process. When the pressure drops suddenly or fluctuates rapidly and the distributed acoustic data shows instantaneous high-frequency pulse characteristics, it is determined to be a local structural response or micro-fracture behavior. When pressure changes occur but distributed acoustic data do not generate a synchronous response in the corresponding depth section, it is determined to be a non-wellbore local event or environmental interference signal.

[0014] Preferably, the optical cable is provided with graduation lines, and the winch is equipped with a measuring device for measuring the length of the optical cable being lowered.

[0015] Secondly, the present invention also proposes a distributed sensing enhancement method for a wire rope-supported logging system, applicable to the distributed sensing enhancement system for the wire rope-supported logging system described in the first aspect, comprising: The optical cable was smoothly lowered to the target well depth using a winch, and the winch meter readings and optical cable calibration information were recorded simultaneously. After the optical cable is laid in place, a wellhead joint calibration operation is performed. The system continuously collects single-mode fiber data using a distributed acoustic sensing system, synchronously collects multimode fiber data using a distributed temperature sensing system, and obtains temperature and pressure values ​​at the target well depth using a tail-mounted point sensor unit. After completing the preset data acquisition task, stop data acquisition and retrieve the optical cable. Remove the tail point sensor unit installed on the optical cable to complete one logging operation cycle.

[0016] Preferably, the wellhead collaborative calibration operation includes: applying a disturbance signal to the optical cable at the wellhead and recording the corresponding vibration response using a distributed acoustic sensing system; and locally heating the optical cable at the wellhead and recording the abnormal temperature response using a distributed temperature sensing system.

[0017] Preferably, after completing the preset data collection task, the method further includes: Based on single-mode fiber data, distributed acoustic data along the length of the optical cable is obtained; based on multimode fiber data, distributed temperature data along the length of the optical cable is obtained. Based on the vibration response corresponding to the disturbance signal recorded by the distributed acoustic sensing system, the reference sampling point of the wellhead location in the distributed acoustic data is determined. Based on the temperature anomaly response corresponding to local heating recorded by the distributed temperature sensing system, the reference sampling point of the wellhead location in the distributed temperature data is determined. Based on the reference sampling points of the wellhead location in the distributed acoustic data and the reference sampling points of the wellhead location in the distributed temperature data, a one-to-one correspondence is established between the distributed sampling points of the optical cable along its length and the actual well depth. Based on the one-to-one correspondence between the distributed sampling points of the optical cable along its length and the actual well depth, the corresponding sampling positions of the target well depth of the tail point sensor unit in the distributed acoustic data and distributed temperature data are determined. Based on the corresponding sampling positions of the tail point sensor unit in the distributed acoustic data and distributed temperature data, the temperature and pressure values ​​obtained by the tail point sensor unit are used as reference quantities to perform reference correction on the distributed acoustic data and distributed temperature data, resulting in corrected distributed acoustic data and distributed temperature data.

[0018] Preferably, the benchmark correction includes one or more of the following: overall offset correction, linear fitting correction, and nonlinear fitting correction.

[0019] In practice, before the optical cable is lowered into the well, optical time domain reflectance (OTDR) tests are performed on the single-mode and multi-mode optical fibers in the optical cable to confirm the fiber path status and effective length. After the test is completed, the optical cable is smoothly lowered to the target well depth by a winch, and the winch meter reading data and optical cable meter mark information are recorded simultaneously during the lowering process. After the optical cable is laid in place, a collaborative calibration operation is performed at the wellhead location. Specifically, this includes: applying a disturbance signal to the optical cable at the wellhead, and the distributed acoustic sensing system recording the corresponding vibration response signal to determine the reference sampling point of the wellhead location in the distributed acoustic data; at the same time, the optical cable at the wellhead is locally heated, and the distributed temperature sensing system recording the abnormal temperature response to determine the reference sampling point of the wellhead location in the distributed temperature data. After calibration, the formal data acquisition phase begins: the distributed acoustic sensing system continuously acquires vibration response signals along the depth direction of the wellbore, the distributed temperature sensing system synchronously acquires distributed temperature data along the length of the optical cable, and the tail point sensor unit acquires the temperature and pressure values ​​at the target well depth. After the monitoring task is completed, data acquisition is stopped, and the optical cable is retrieved from the well to the cable reel by a winch. The tail point sensor unit on the optical cable is then removed, completing one complete logging operation cycle. During data processing, a correspondence between distributed sampling points and actual well depths is established based on the reference sampling points of the wellhead location in the distributed acoustic data and the reference sampling points of the wellhead location in the distributed temperature data. The distributed optical fiber acquisition system acquires continuous physical quantity change information along the well shaft direction as relative change data, while the point-type temperature and pressure measurement components installed at the end of the optical cable synchronously acquire the absolute parameter values ​​at the corresponding depth position; by using the point measurement results as absolute reference values, the distributed data is uniformly calibrated, realizing the conversion of distributed sensing data from relative quantities to absolute quantities.

[0020] The distributed sensing enhancement system and method proposed in this invention, under the wire rope bearing logging operation system, maintains the wire rope bearing logging operation process and engineering system unchanged, does not increase the complexity of downhole mechanical structures, and does not significantly increase the operation cost. By improving the bearing medium and the function of the logging system, it enables the traditional wire rope logging operation, which only has point measurement capabilities, to have continuous distributed sensing capabilities along the wellbore direction. This enhances the data dimension of traditional logging methods, improves the engineering interpretability and reliability of distributed measurement data, and performs fusion calibration through point absolute measurements of the tail point sensor unit, enabling the distributed data to have absolute quantity expression capabilities. This significantly improves the spatial resolution and interpretation completeness of downhole parameters and reduces the need for repeated downhole operations. Attached Figure Description

[0021] Figure 1 This is a schematic diagram of the structure of a distributed sensing enhancement system under a wire rope-supported well logging operation system proposed in this invention. Detailed Implementation

[0022] It should be noted that, unless otherwise specified, the embodiments and features described in the present invention can be combined with each other. The present invention will now be described in detail with reference to the accompanying drawings and embodiments.

[0023] Firstly, referring to Figure 1 The present invention proposes a distributed sensing enhancement system under a wire rope bearing logging operation system, comprising: a winch optical cable unit, a tail point sensor unit, a ground distributed acquisition unit, and a data fusion and calibration unit. The winch optical cable unit includes a winch and a carrying optical cable wound on it. The optical cable integrates single-mode optical fiber and multi-mode optical fiber while meeting the tension and depth requirements of wire rope bearing logging operations. The optical cable is equipped with scale lines for depth positioning. The tail point sensor unit is installed at the tail of the optical cable to acquire absolute physical quantity signals at the corresponding depth position downhole. The tail point sensor unit includes temperature and pressure measurement components. The ground-based distributed acquisition unit includes a distributed acoustic sensing system connected to a single-mode optical fiber and a distributed temperature sensing system connected to a multimode optical fiber. The distributed acoustic sensing system is used to acquire continuous vibration response data (i.e., single-mode optical fiber data) of the single-mode optical fiber, and the distributed temperature sensing system is used to acquire continuous temperature response data (i.e., multimode optical fiber data) of the multimode optical fiber. The data fusion and calibration unit is used to obtain distributed acoustic data along the length of the optical cable based on single-mode optical fiber data; to obtain distributed temperature data along the length of the optical cable based on multimode optical fiber data; and to obtain corrected distributed acoustic data and distributed temperature data based on the temperature and pressure values ​​at the target well depth, as well as the distributed acoustic data and distributed temperature data.

[0024] This invention does not replace traditional point logging methods with distributed optical fiber technology. Instead, it enhances the functionality of the supporting medium and the data processing flow of the wire rope logging system, without adding complex downhole mechanical structures or significantly increasing operating costs. This gives the traditional wire rope logging system, which only has single-point measurement capabilities, continuous distributed sensing capabilities along the wellbore direction. This allows for the acquisition of more continuous and richer downhole parameter information in a single downhole operation, thus enhancing the data dimension of the system. Furthermore, by using point absolute measurements from the tail-end point sensor unit for fusion calibration, the distributed data gains absolute quantity representation capabilities, significantly improving the spatial resolution and interpretability of downhole parameters and reducing the need for repeated downhole operations.

[0025] It is important to understand that the winch and the carrying optical cable in this embodiment simultaneously satisfy the functions of mechanical load-bearing and optical signal transmission. Its mechanical strength design meets the requirements of the well depth and tension in wire rope logging operations, so that it can be directly used as the carrying medium of wire rope in engineering applications without changing the existing winch structure or wellhead layout.

[0026] Specifically, the optical cable is connected to single-mode and multi-mode patch cords via fusion splicing and then connected to the ground acquisition unit.

[0027] In some embodiments, based on the temperature and pressure values ​​at the target well depth, and distributed acoustic data and distributed temperature data, corrected distributed acoustic data and distributed temperature data are obtained, specifically including: Establish a one-to-one correspondence between the distributed sampling points of the optical cable along its length and the actual well depth; Based on the one-to-one correspondence between the distributed sampling points of the optical cable along its length and the actual well depth, the corresponding sampling positions of the target well depth of the tail point sensor unit in the distributed acoustic data and distributed temperature data are determined. Based on the corresponding sampling positions of the tail point sensor unit in the distributed acoustic data and distributed temperature data, the temperature and pressure values ​​obtained by the tail point sensor unit are used as reference quantities to perform reference correction on the distributed acoustic data and distributed temperature data, resulting in corrected distributed acoustic data and distributed temperature data.

[0028] In a further embodiment, establishing a one-to-one correspondence between the distributed sampling points along the length of the optical cable and the actual well depth specifically includes: When the optical cable is lowered to the target well depth, a disturbance signal is applied to the optical cable at the wellhead, and the corresponding vibration response is recorded using a distributed acoustic sensing system. Local heating is applied to the optical cable at the wellhead, and a distributed temperature sensing system is used to record abnormal temperature responses. Based on the vibration response corresponding to the disturbance signal recorded by the distributed acoustic sensing system, the reference sampling point of the wellhead location in the distributed acoustic data is determined. Based on the temperature anomaly response corresponding to local heating recorded by the distributed temperature sensing system, the reference sampling point of the wellhead location in the distributed temperature data is determined. Based on the reference sampling points of the wellhead location in the distributed acoustic data and the reference sampling points of the wellhead location in the distributed temperature data, a correspondence between the distributed sampling points of the optical cable along its length and the actual well depth is established.

[0029] This embodiment uses point measurement results as absolute reference values ​​to perform overall offset correction or fitting correction on distributed data, thereby realizing the transformation of distributed sensing data from relative quantities to absolute quantities, thus enabling continuous distributed data to have the absolute physical quantity meaning required for engineering interpretation.

[0030] In a further embodiment, the benchmark correction includes one or more of global offset correction, linear fit correction, and nonlinear fit correction.

[0031] In some embodiments, a wellhead installation device is also included, including a fixed pulley, a guide wheel, or a guide frame. The wellhead installation device is used to change the direction of the optical cable entering the well, limit the bending radius, and reduce friction damage at the wellhead.

[0032] In some embodiments, the optical cable is provided with graduation lines, and the winch is equipped with a meter for measuring the length of the optical cable being lowered.

[0033] In a further embodiment, after obtaining the corrected distributed acoustic data and distributed temperature data, the method further includes: The system detects whether the temperature and pressure values ​​at the target well depth exhibit abrupt changes, periodic fluctuations, or trend changes within a certain time period. If so, it determines that there are real physical process changes downhole (fluid disturbance, local micro-fractures, casing deformation), and uses this time period as the effective analysis window. Within this effective analysis window, it extracts the distributed acoustic data corresponding to the depth segment of the target well depth and analyzes the vibration amplitude and spectral characteristics of the distributed acoustic data. When distributed acoustic data shows amplitude or spectral characteristic changes consistent with the pressure change trend in the same depth section, the state type of the well section is determined by combining the pressure change direction and amplitude characteristics.

[0034] During the state type determination process, when the pressure increases and the distributed acoustic data shows a continuously enhanced low-frequency vibration component in the corresponding depth segment, it is determined to be a fluid flow or injection disturbance process. When the pressure drops suddenly or fluctuates rapidly and the distributed acoustic data shows instantaneous high-frequency pulse characteristics, it is determined to be a local structural response or micro-fracture behavior. When pressure changes occur but distributed acoustic data do not generate a synchronous response in the corresponding depth section, it is determined to be a non-wellbore local event or environmental interference signal.

[0035] This embodiment can jointly interpret the distributed acoustic data after depth unification and the pressure value of the tail point sensor unit for identification of downhole condition changes.

[0036] Secondly, the present invention also proposes a distributed sensing enhancement method for a wire rope-supported logging system, applicable to the distributed sensing enhancement system for a wire rope-supported logging system as described in any one of the first aspects, comprising: The optical cable is lowered smoothly using a winch, and the winch meter readings and optical cable markings are recorded simultaneously during the lowering process. After the optical cable is lowered to the target well depth, a wellhead calibration operation is performed. After the calibration operation is completed, the distributed acoustic sensing system continuously collects single-mode fiber data, the distributed temperature sensing system synchronously collects multimode fiber data, and the tail point sensor unit simultaneously obtains the temperature and pressure values ​​at the target well depth. After completing the preset data acquisition task, data acquisition is stopped, and the optical cable is retrieved by a winch, completing one complete logging operation cycle.

[0037] In some embodiments, the wellhead collaborative calibration operation specifically includes: A mechanical disturbance signal is applied to the optical cable at the wellhead, and the vibration response is recorded using a distributed acoustic system. At the same time, the optical cable at the wellhead is locally heated, and a distributed temperature system is used to record the temperature anomaly response.

[0038] In some embodiments, after completing the preset data collection task, the method further includes: Based on single-mode fiber data, distributed acoustic data along the length of the optical cable is obtained; based on multimode fiber data, distributed temperature data along the length of the optical cable is obtained. Based on the vibration response corresponding to the disturbance signal recorded by the distributed acoustic sensing system, the reference sampling point of the wellhead location in the distributed acoustic data is determined. Based on the temperature anomaly response corresponding to local heating recorded by the distributed temperature sensing system, the reference sampling point of the wellhead location in the distributed temperature data is determined. Based on the reference sampling points of the wellhead location in the distributed acoustic data and the reference sampling points of the wellhead location in the distributed temperature data, a one-to-one correspondence is established between the distributed sampling points of the optical cable along its length and the actual well depth. Based on the one-to-one correspondence between the distributed sampling points of the optical cable along its length and the actual well depth, the corresponding sampling positions of the target well depth of the tail point sensor unit in the distributed acoustic data and distributed temperature data are determined. Based on the corresponding sampling positions of the tail point sensor unit in the distributed acoustic data and distributed temperature data, the temperature and pressure values ​​obtained by the tail point sensor unit are used as reference quantities to perform reference correction on the distributed acoustic data and distributed temperature data, thereby obtaining the corrected distributed acoustic data and distributed temperature data, realizing the conversion of distributed vibration and temperature data from relative changes to absolute physical quantities.

[0039] The benchmark correction includes one or more of the following: overall offset correction, linear fitting correction, and nonlinear fitting correction.

[0040] In some embodiments, after obtaining the corrected distributed acoustic data and distributed temperature data, the method further includes: The system detects whether the temperature and pressure values ​​at the target well depth exhibit abrupt changes, periodic fluctuations, or trends within a certain time period. If so, this time period is used as the effective analysis window. Within this effective analysis window, the distributed acoustic data corresponding to the depth segment of the target well depth is extracted, and the vibration amplitude and spectral characteristics of the distributed acoustic data are analyzed. When distributed acoustic data shows amplitude or spectral characteristic changes consistent with the pressure change trend in the same depth section, the state type of the well section is determined by combining the pressure change direction and amplitude characteristics.

[0041] During the state type determination process, when the pressure increases and the distributed acoustic data shows a continuously enhanced low-frequency vibration component in the corresponding depth segment, it is determined to be a fluid flow or injection disturbance process. When the pressure drops suddenly or fluctuates rapidly and the distributed acoustic data shows instantaneous high-frequency pulse characteristics, it is determined to be a local structural response or micro-fracture behavior. When pressure changes occur but distributed acoustic data do not generate a synchronous response in the corresponding depth section, it is determined to be a non-wellbore local event or environmental interference signal.

[0042] In some embodiments, prior to lowering the optical cable via a winch, the method further includes: Optical time-domain reflectometry was performed on single-mode and multimode optical fibers in the optical cable to confirm the fiber path status and effective length, ensuring that the target well depth is within the effective working range of the optical fiber.

[0043] The distributed sensing enhancement system and method under the wire rope bearing logging operation system of the present invention, while maintaining the existing wire rope bearing logging operation process and engineering structure, enhances the traditional single-point logging capability to continuous distributed logging capability by introducing distributed acquisition capability and a fusion calibration mechanism based on point absolute measurement. This enables the distributed data to have the ability to express absolute physical quantities, thereby improving the continuity, completeness and reliability of wellbore parameter acquisition and engineering interpretation.

[0044] The above description is merely a preferred embodiment of the present invention, and the scope of protection of the present invention is not limited thereto. Any equivalent substitutions or modifications made by those skilled in the art within the scope of the technology disclosed in the present invention, based on the technical solution and inventive concept of the present invention, should be covered within the scope of protection of the present invention.

Claims

1. A distributed perception augmentation system under a wireline borehole servicing system, characterized in that, include: The winch-optical cable unit includes a winch and an optical cable, wherein the optical cable integrates at least one single-mode optical fiber and at least one multimode optical fiber; The tail-end point sensor unit is fixedly installed at the end of the optical cable to obtain temperature and pressure values ​​at the target well depth. The ground-based distributed acquisition unit includes a distributed acoustic sensing system connected to a single-mode fiber and a distributed temperature sensing system connected to a multimode fiber, used to acquire single-mode fiber data and multimode fiber data. The data fusion and calibration unit is used to obtain distributed acoustic data along the length of the optical cable based on single-mode fiber data. Based on multimode fiber data, distributed temperature data along the length of the optical cable is obtained; based on the temperature and pressure values ​​at the target well depth, as well as distributed acoustic data and distributed temperature data, corrected distributed acoustic data and distributed temperature data are obtained.

2. The distributed perception enhancement system under wireline logging operation system of claim 1, wherein, Based on the temperature and pressure values ​​at the target well depth, as well as distributed acoustic and temperature data, corrected distributed acoustic and temperature data are obtained, specifically including: Establish a one-to-one correspondence between the distributed sampling points of the optical cable along its length and the actual well depth; Based on the one-to-one correspondence between the distributed sampling points of the optical cable along its length and the actual well depth, the corresponding sampling positions of the target well depth of the tail point sensor unit in the distributed acoustic data and distributed temperature data are determined. Based on the corresponding sampling positions of the tail point sensor unit in the distributed acoustic data and distributed temperature data, the temperature and pressure values ​​obtained by the tail point sensor unit are used as reference quantities to perform reference correction on the distributed acoustic data and distributed temperature data, resulting in corrected distributed acoustic data and distributed temperature data.

3. The distributed sensing enhancement system under the wire rope-supported logging operation system according to claim 2, characterized in that, Establish a one-to-one correspondence between the distributed sampling points along the length of the optical cable and the actual well depth, specifically including: When the optical cable is lowered to the target well depth, a disturbance signal is applied to the optical cable at the wellhead, and the corresponding vibration response is recorded using a distributed acoustic sensing system; the optical cable at the wellhead is locally heated, and the abnormal temperature response is recorded using a distributed temperature sensing system. Based on the vibration response corresponding to the disturbance signal recorded by the distributed acoustic sensing system, the reference sampling point of the wellhead location in the distributed acoustic data is determined. Based on the temperature anomaly response corresponding to local heating recorded by the distributed temperature sensing system, the reference sampling point of the wellhead location in the distributed temperature data is determined. Based on the reference sampling points of the wellhead location in the distributed acoustic data and the reference sampling points of the wellhead location in the distributed temperature data, a correspondence between the distributed sampling points of the optical cable along its length and the actual well depth is established.

4. The distributed sensing enhancement system under the wire rope bearing logging operation system according to claim 3, characterized in that, Benchmark correction includes one or more of the following: global offset correction, linear fit correction, and nonlinear fit correction.

5. The distributed perception enhancement system under wireline logging operation system of claim 1, wherein, After obtaining the corrected distributed acoustic data and distributed temperature data, the following is also included: The system detects whether the temperature and pressure values ​​at the target well depth exhibit abrupt changes, periodic fluctuations, or trends within a certain time period. If so, this time period is used as the effective analysis window. Within this effective analysis window, the distributed acoustic data corresponding to the depth segment of the target well depth is extracted, and the vibration amplitude and spectral characteristics of the distributed acoustic data are analyzed. When distributed acoustic data shows amplitude or spectral characteristics that are consistent with the pressure change trend in the same depth section, the state type of the well section is determined by combining the pressure change direction and amplitude characteristics. Preferably, in the process of determining the state type, when the pressure increases and the distributed acoustic data shows a continuously enhanced low-frequency vibration component in the corresponding depth segment, it is determined to be a fluid flow or injection disturbance process. When the pressure drops suddenly or fluctuates rapidly and the distributed acoustic data shows instantaneous high-frequency pulse characteristics, it is determined to be a local structural response or micro-fracture behavior. When pressure changes occur but distributed acoustic data do not generate a synchronous response in the corresponding depth section, it is determined to be a non-wellbore local event or environmental interference signal.

6. The distributed perception enhancement system under wireline borehole servicing system of claim 1, wherein, The optical cable is equipped with graduation lines, and the winch is equipped with a measuring device for measuring the length of the optical cable being lowered.

7. A distributed sensing enhancement method under a wireline logging operation system, applied to the distributed sensing enhancement system under the wireline logging operation system of any one of claims 1-6, characterized in that, include: The optical cable was smoothly lowered to the target well depth using a winch, and the winch meter readings and optical cable calibration information were recorded simultaneously. After the optical cable is laid in place, a wellhead joint calibration operation is performed. The system continuously collects single-mode fiber data using a distributed acoustic sensing system, synchronously collects multimode fiber data using a distributed temperature sensing system, and obtains temperature and pressure values ​​at the target well depth using a tail-mounted point sensor unit. After completing the preset data acquisition task, stop data acquisition and retrieve the optical cable. Remove the tail point sensor unit installed on the optical cable to complete one logging operation cycle.

8. The distributed sensing enhanced method under wireline borehole servicing system of claim 7, wherein, Wellhead co-calibration operations include: A disturbance signal is applied to the optical cable at the wellhead, and the corresponding vibration response is recorded using a distributed acoustic sensing system. The optical cable at the wellhead is locally heated, and a distributed temperature sensing system is used to record abnormal temperature responses to determine the wellhead location as a reference sampling point in the distributed temperature data.

9. The distributed sensing enhanced method under wireline borehole servicing system of claim 7, wherein, After completing the preset data collection task, it also includes: Based on single-mode fiber data, distributed acoustic data along the length of the optical cable is obtained; based on multimode fiber data, distributed temperature data along the length of the optical cable is obtained. Based on the vibration response corresponding to the disturbance signal recorded by the distributed acoustic sensing system, the reference sampling point of the wellhead location in the distributed acoustic data is determined. Based on the temperature anomaly response corresponding to local heating recorded by the distributed temperature sensing system, the reference sampling point of the wellhead location in the distributed temperature data is determined. Based on the reference sampling points of the wellhead location in the distributed acoustic data and the reference sampling points of the wellhead location in the distributed temperature data, a one-to-one correspondence is established between the distributed sampling points of the optical cable along its length and the actual well depth. Based on the one-to-one correspondence between the distributed sampling points of the optical cable along its length and the actual well depth, the corresponding sampling positions of the target well depth of the tail point sensor unit in the distributed acoustic data and distributed temperature data are determined. Based on the corresponding sampling positions of the tail point sensor unit in the distributed acoustic data and distributed temperature data, the temperature and pressure values ​​obtained by the tail point sensor unit are used as reference quantities to perform reference correction on the distributed acoustic data and distributed temperature data, resulting in corrected distributed acoustic data and distributed temperature data.

10. The distributed perception augmentation method under a wireline borehole servicing system of claim 9, wherein, Benchmark correction includes one or more of the following: global offset correction, linear fit correction, and nonlinear fit correction.

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