High-temperature and high-pressure resistant digital geothermal multi-parameter collaborative well logging system and intelligent analysis method

Abstract

The application provides a high-temperature and high-pressure-resistant digital geothermal multi-parameter collaborative well logging system and an intelligent analysis method, and relates to the technical field of digital geothermal resource monitoring and control. The application comprises a downhole logging subsystem, a wellhead transmission and energy supply subsystem and a ground digital processing and collaborative analysis subsystem. The system realizes the synchronous collection of temperature, pressure, flow and electrical parameters under the unified clock and depth reference, ensures the continuous uplink of data through anti-interference transmission and error correction coding, performs the same well section registration and collaborative inversion based on the working condition constraints at the ground end, automatically generates the layered temperature and pressure flow characteristics, permeability representation and wellbore integrity index, realizes the closed loop from data acquisition to intelligent decision, and improves the geothermal well logging accuracy and intelligent level.

Description

Technical Field

[0001] This invention relates to the field of digital geothermal resource monitoring and control technology, and in particular to a high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system and intelligent analysis method. Background Technology

[0002] Geothermal well logging has evolved from simple temperature or pressure measurements to acquiring multiple parameters, including temperature, pressure, flow rate, electrical properties, and acoustic properties, in a single well run and transmitting them back in real time via cable or fiber optic cable. A typical system consists of three loosely connected parts: a downhole tool string, wellhead power supply and relay, and surface acquisition and interpretation. This system can generate fundamental results such as temperature-pressure curves, production zone delineation, and wellbore integrity assessment, meeting the needs of conventional exploration and pilot production in shallow, medium, and deep wells.

[0003] With the increase in deep and ultra-deep high-temperature and high-pressure wells, the industry is shifting towards an integrated digital logging system that features "single-trip multi-parameter synchronization, same-section registration, ground collaborative calculation, and write-back control": the downhole end samples in parallel under a unified clock and a unified depth benchmark and generates data frames with time and depth markers; the wellhead end achieves stable power supply and interference-resistant transmission; the ground end completes decoding, same-section registration, and consistency verification using a digital process, and outputs hierarchical indicators that can directly drive production decisions when combined with working conditions and geological constraints.

[0004] Existing solutions generally suffer from problems such as inconsistent time scales, depth benchmark drift, channel noise and data packet loss, and lack of consistency measurement interfaces for cross-parameter interpretation. These issues lead to unstable collaborative analysis, unusable results, and a non-closed-loop data and control chain from downhole to the surface, making it difficult to achieve reliable "measurement and judgment" applications under high temperature and high pressure environments. Summary of the Invention

[0005] To overcome the shortcomings of existing technologies, the purpose of this invention is to provide a high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system and intelligent analysis method. By achieving synchronous acquisition of multiple parameters, anti-interference transmission, registration within the same well section, collaborative inversion, and closed-loop control under high-temperature and high-pressure environments, an integrated digital system for geothermal logging from data acquisition to intelligent decision-making is constructed, significantly improving the logging accuracy and operational intelligence level of deep geothermal resource development.

[0006] To achieve the above objectives, the present invention provides the following solution:

[0007] A high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system includes:

[0008] The downhole logging subsystem consists of a high-temperature and high-pressure resistant encapsulated multi-parameter sensor string, a unified clock and depth reference unit, and an edge acquisition and encoding unit. The multi-parameter sensor string is used to sample temperature, pressure, flow rate, and electrical data in parallel under the same time scale and the same depth reference to obtain sampling results. The edge acquisition and encoding unit is used to perform time and depth marking, anomaly removal, and error correction encoding on the sampling results to generate downhole data frames.

[0009] The wellhead transmission and power supply subsystem is electrically connected to the downhole logging subsystem and is used to provide steady-state power supply and uplink to continuously forward the downhole data frames to the surface in an anti-interference manner.

[0010] The surface digital processing and collaborative analysis subsystem is used to sequentially execute the reception and decoding of the downhole data frames, time-scale correction and registration within the same well section, cross-parameter consistency verification and collaborative inversion under operating condition constraints, output stratified temperature, pressure and flow characteristics, permeability characterization and wellbore integrity indicators, and generate alarm and dispatch instructions for production.

[0011] Preferably, the high-temperature and high-pressure resistant encapsulation of the downhole logging subsystem adopts a metal sealing and heat insulation and vibration isolation structure. The multi-parameter sensor string and the edge acquisition and encoding unit can work continuously under the condition that the upper limit of temperature resistance is not less than 150℃ and the upper limit of pressure resistance is not less than 70MPa, and the stability of the unified clock and depth reference unit can be maintained within the full temperature and pressure range to meet the synchronous sampling requirements.

[0012] Preferably, the unified clock and depth reference unit includes a high-stability clock and a depth measurement combination. The high-stability clock is used to provide the same time scale for parallel sampling and time stamping. The depth measurement combination is used to fuse with the ground depth reference to form the same depth reference. The ground digital processing and collaborative analysis subsystem performs time scale correction and registration within the same well section on the uplink downhole data frames to achieve reliable comparison of multiple parameters within the same well section.

[0013] Preferably, the edge acquisition and encoding unit further performs error control and robust transmission preprocessing when generating downhole data frames; the error control includes one of cyclic redundancy check and forward error correction; the robust transmission preprocessing includes one of interleaving or data buffering to support breakpoint resumption and complete reassembly after data packet loss.

[0014] Preferably, the wellhead transmission and power supply subsystem is a hybrid power supply and communication architecture, supporting at least one physical medium, such as cable or optical fiber, and the wellhead transmission and power supply subsystem is equipped with an uplink adaptive bit rate and selective retransmission mechanism.

[0015] Preferably, the ground digital processing and collaborative analysis subsystem introduces operating condition and physical constraints during cross-parameter consistency verification; the constraints include at least one of mass conservation, energy conservation, or flow continuity.

[0016] A smart analysis method for a high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system, applied to the aforementioned logging system, the method comprising:

[0017] Under a unified clock and a unified depth benchmark, the downhole logging subsystem samples temperature, pressure, flow rate, and electrical parameters in parallel to obtain the sampling results;

[0018] The sampling results are time-stamped and depth-stamped, and anomaly removal and error correction coding are performed to generate downhole data frames;

[0019] The uplink data frame from the wellhead transmission and power supply subsystem is continuously forwarded to the surface to obtain uplink data packets.

[0020] The uplink data packets are received and decoded using the terrestrial digital processing and collaborative analysis subsystem to recover the time stamps and depth stamps, forming the original dataset.

[0021] Based on a unified clock and a unified depth benchmark, time-scale correction and registration within the same well section are performed on the original dataset to obtain an aligned dataset.

[0022] Based on at least one of the constraints of mass conservation, energy conservation, or flow continuity, the aligned dataset is subjected to consistency verification and quality labeling, and a dataset with quality labeling is output.

[0023] Under the constraints and quality label conditions, the dataset with quality label is subjected to collaborative inversion to output stratified temperature-pressure-flow characteristics, permeability characterization and wellbore integrity index, collectively referred to as stratified index;

[0024] Alarms and dispatch instructions are generated based on the hierarchical indicators and output to the field execution terminal through a standardized interface.

[0025] Preferably, it further includes:

[0026] The execution feedback of the alarm and dispatch commands and the corresponding operating condition data are collected to form a feedback record. The feedback record is then associated with the alignment dataset and archived for adaptive updates of registration and collaborative inversion within the same well section.

[0027] Preferably, based on at least one constraint of mass conservation, energy conservation, or flow continuity, the aligned dataset is subjected to consistency verification and quality labeling, and a dataset with quality labeling is output, including:

[0028] To align the dataset at adjacent depth sampling points Depth cells are formed, and discrete residuals are established according to the mass conservation principle, using the following formula: ;in, For depth position Fluid density at that location; For depth position Fluid density at that location; This refers to the effective flow cross-sectional area of ​​the well section; For depth position The average flow velocity at that location; For depth position The average flow velocity at that location; The overall compressibility coefficient of the fluid and the formation medium; The depth spacing between adjacent sampling points; For depth position Pressure at the location; For depth position Pressure at the location; The time sampling interval for aligning the dataset; This represents the mass-conserved residual for the depth element.

[0029] right Error propagation is performed to obtain the residual standard deviation, using the following formula: ;in, The standard deviation of the residuals; The equivalent standard deviation of density converted from temperature and pressure; The standard deviation of flow rate converted to flow velocity; This represents the standard deviation of the pressure measurement.

[0030] Calculate the standardized residuals and assign quality labels based on the standardized residuals, using the following formula: ;in, For standardized residuals; when The depth cell is marked as "qualified" when... The result is marked as "unqualified" and written into the dataset with quality labels;

[0031] For both "qualified" and "unqualified" depth cells, a confidence score is output simultaneously, using the following formula: ;in, The confidence score is based on the Gaussian assumption.

[0032] Preferably, alarm and dispatch instructions are generated based on the hierarchical indicators and output to the field execution terminal through a standardized interface, including:

[0033] The set of hierarchical indicators is parsed, and the mapping from indicators to actions is completed based on a preset threshold table and rule base, forming instruction candidates and priorities;

[0034] According to the priority, the conflict resolution and merging of the instruction candidates are performed to generate alarm and dispatch instructions, and each instruction is accompanied by the execution object, target value, execution time limit and effective conditions.

[0035] The alarm and dispatch instructions are encapsulated into an instruction message, with a timestamp and sequence number added. Integrity verification and signature verification are performed to obtain the message to be sent.

[0036] The message to be sent is output to the field execution terminal through a standardized interface, and the execution confirmation receipt is received and associated with the corresponding level indicators for archiving.

[0037] The present invention discloses the following technical effects:

[0038] (1) This invention addresses the problem of sensor instability in high-temperature and high-pressure geothermal wells. By adopting a high-temperature and high-pressure resistant packaging structure and a unified clock and depth reference unit design, the multi-parameter sensor can still maintain synchronous sampling and signal stability in well sections with temperatures above 150°C and pressure below 70MPa, significantly improving measurement accuracy and data reliability under extreme conditions.

[0039] (2) In view of the problem of asynchronous time and depth of multi-parameter logging data, this invention uses a unified clock synchronization mechanism and depth benchmark fusion algorithm to complete time and depth marking in real time downhole, realize the alignment of temperature, pressure, flow and electrical parameters in the same well section, and provide an accurate and unified data benchmark for collaborative analysis among multiple parameters.

[0040] (3) In view of the problem of unstable uplink transmission in deep wells, this invention proposes an integrated architecture of wellhead transmission and power supply. Through anti-interference communication links and error correction coding, the downhole data frames can be continuously and stably transmitted under high temperature and high pressure, ensuring the integrity and temporal continuity of logging data.

[0041] (4) In view of the problem that ground analysis relies on manual labor and the interpretation results are scattered, the present invention constructs a ground digital processing and collaborative analysis subsystem. It adopts registration in the same well section, cross-parameter consistency verification and collaborative inversion under working condition constraints to realize the automatic generation of layered temperature and pressure flow characteristics, permeability characterization and wellbore integrity index, which greatly improves the analysis efficiency and the consistency of conclusions.

[0042] (5) In view of the problem that traditional systems lack real-time control feedback, this invention sets up a standardized interface to directly convert the hierarchical indicators generated by analysis into alarm and dispatch instructions and output them to the field execution terminal. It also associates the execution feedback with the working condition data and writes it back, realizing digital closed-loop management from logging to control, and improving the safety of well operation and the intelligence level of geothermal system. Attached Figure Description

[0043] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0044] Figure 1 This is a schematic diagram of the system structure provided in an embodiment of the present invention;

[0045] Figure 2 This is a flowchart of a method provided in an embodiment of the present invention. Detailed Implementation

[0046] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0047] The purpose of this invention is to provide a high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system and intelligent analysis method, which realizes synchronous measurement, stable transmission, intelligent analysis and closed-loop control of multiple parameters under high-temperature and high-pressure conditions of geothermal wells. It overcomes the lack of reliability and intelligence of traditional logging systems in deep and complex environments, and significantly improves the accuracy and automation level of geothermal resource exploration and development.

[0048] To make the above-mentioned objects, features and advantages of the present invention more apparent and understandable, the present invention will be further described in detail below with reference to the accompanying drawings and specific embodiments.

[0049] Figure 1 This is a schematic diagram of the system structure provided in an embodiment of the present invention, such as... Figure 1 As shown, this invention provides a high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system, comprising:

[0050] The downhole logging subsystem consists of a high-temperature and high-pressure resistant encapsulated multi-parameter sensor string, a unified clock and depth reference unit, and an edge acquisition and encoding unit. The multi-parameter sensor string is used to sample temperature, pressure, flow rate, and electrical data in parallel under the same time scale and the same depth reference to obtain sampling results. The edge acquisition and encoding unit is used to perform time and depth marking, anomaly removal, and error correction encoding on the sampling results to generate downhole data frames.

[0051] The wellhead transmission and power supply subsystem is electrically connected to the downhole logging subsystem and is used to provide steady-state power supply and uplink to continuously forward the downhole data frames to the surface in an anti-interference manner.

[0052] The surface digital processing and collaborative analysis subsystem is used to sequentially execute the reception and decoding of the downhole data frames, time-scale correction and registration within the same well section, cross-parameter consistency verification and collaborative inversion under operating condition constraints, output stratified temperature, pressure and flow characteristics, permeability characterization and wellbore integrity indicators, and generate alarm and dispatch instructions for production.

[0053] Specifically, this embodiment employs an integrated encapsulation process combining metal sealing and thermal insulation / vibration isolation to realize the downhole logging subsystem. The outer shell is made of a high-temperature alloy tube, with multiple layers of ceramic thermal insulation pads and aerogel layers laid on the inner wall. Elastic vibration-damping supports are installed between the sensor and the tube to absorb axial and radial impacts. Both ends use metal annular seals with a conical pre-tightening structure, ensuring continuous operation and stable sealing under high-temperature and high-pressure conditions of 150℃ to 180℃ and 70MPa to 80MPa. The multi-parameter sensor string has a modular plug-in structure, including temperature, pressure, flow, and electrical sensing modules. Each module is connected to the internal data bus via a high-temperature resistant connector, ensuring the reliability of electrical connections under high-temperature environments. After 100 hours of high-temperature and high-pressure autoclave testing, the encapsulation structure showed no leakage or signal drift across the entire temperature and pressure range, meeting the requirements for long-term continuous downhole measurement. In this embodiment, the so-called "unified clock and depth reference unit" refers to a functional module that provides a unified time and depth reference for all downhole sensing modules, ensuring that all parameters are sampled synchronously under the same time scale and depth reference.

[0054] In this embodiment, the edge acquisition and encoding unit is located inside the downhole tool body and is responsible for data acquisition, processing, and packaging. Its core circuitry includes a high-stability clock source, an analog-to-digital converter, a data buffer, and an error correction and encoding module. This unit triggers sampling commands with a 1-millisecond time resolution and marks the well depth position with a 1-centimeter depth resolution. After acquiring temperature, pressure, flow rate, and electrical sample values, the edge acquisition and encoding unit immediately performs anomaly rejection, including out-of-limit rejection, abrupt change smoothing, and missing measurement compensation. It then performs error control and message encapsulation on the processing results. The message fields include a time stamp, a depth stamp, parameter data segments, and an integrity check segment. After forming a downhole data frame, it is continuously transmitted to the surface via an anti-interference communication link, achieving a closed-loop data transmission from sampling to uplink. In this embodiment, the "edge acquisition and encoding unit" refers to an electronic processing module integrated within the downhole tool that performs parallel acquisition, preprocessing, time and depth marking, error correction encoding, and message generation before the data reaches the surface. Its function is to perform data quality control and transmission preparation downhole, ensuring the integrity and consistency of the data received on the surface.

[0055] Furthermore, this embodiment integrates the unified clock and depth reference unit into the downhole tool head circuit compartment. The unified clock employs a temperature-compensated high-stability oscillator source and a temperature-controlled crystal in a collaborative design, achieving a time-frequency stability better than ±0.5ppm and continuous operation for at least 100 hours in a downhole environment of 150℃. The first frame is synchronized via a time alignment pulse sent from the wellhead, and a consistent time scale is maintained throughout subsequent sampling periods using a "master clock distribution—local counting verification—drift compensation" link, with a time mark resolution of 1 millisecond. The depth measurement assembly consists of a logging cable winch encoder, downhole acceleration and tilt sensing components, and a wellhead pressure-density conversion depth module. After sampling, coarse registration is performed downhole, and depth markings are applied, with a depth resolution of 1 centimeter. To avoid ambiguity in terminology, in this embodiment, "unified clock and depth reference unit" refers to a functional module that provides a unified time reference and a unified depth reference downhole. Its function is to enable the four types of parameters—temperature, pressure, flow rate, and electrical properties—to be sampled in parallel and accurately marked at the same time and depth reference. "Depth measurement combination" refers to the device for jointly acquiring the above three depth information channels. Its function is to improve the reliability of depth markings under static, jacking / jacking, jamming, and elastic elongation conditions. In this embodiment, the surface digital processing and collaborative analysis subsystem, upon receiving uplink downhole data frames, first performs time-scale correction based on the first frame's time alignment pulse and subsequent frame time markers. If the detected cumulative error exceeds 2 milliseconds, it immediately triggers drift back and performs linear interpolation correction on adjacent frames. Subsequently, it performs registration within the same well section: using the surface depth reference as the main axis, it calls the winch encoder curve for initial registration, and then uses the downhole acceleration-inclination calculated trajectory and pressure-density converted depth as verification channels to perform consistency checks on each depth unit. If the maximum deviation of the three depths under the same time scale does not exceed 2 centimeters, the registration of that depth unit is confirmed to be valid. If the threshold is exceeded, the system reweights according to the "master-slave priority and confidence" strategy and falls back to the nearest reliable depth unit, ensuring that temperature, pressure, flow, and electrical data within the same well section can be reliably compared. For ease of understanding, in this embodiment, "registration within the same well section" refers to the processing flow of aligning depth markers of different parameters to the same depth unit under a unified time reference. Its function is to ensure spatial consistency between multiple parameters, thereby supporting subsequent collaborative analysis and command generation.

[0056] In this embodiment, when generating data frames downhole, the edge acquisition and encoding unit sequentially performs error control and robust transmission preprocessing: First, error control is completed, preferably using "CCITT-16" or "CRC-32C" with cyclic redundancy check to add a check field to the end of each data frame, and forward error correction is enabled in high-interference well sections, preferably using the (255,223) or (255,239) parameter set of Reed-Solomon error correction code to achieve automatic correction of sudden errors; then, robust transmission preprocessing is performed, where "interleaving" refers to breaking down and rearranging the parameter data segments in a data frame according to a fixed block length to distribute continuous errors to multiple blocks. In this embodiment, the interleaving block length is 128 bytes or 256 bytes; "data buffering" refers to setting a circular buffer queue at the downhole end before the frame is generated. In this embodiment, the circular buffer capacity is not less than 512 kilobytes, which is used to retain pending and unacknowledged data segments in the event of short-term power failure or link jitter. To support breakpoint resumption and complete reassembly after packet loss, each data frame carries a frame sequence number, a timestamp, and an intra-frame fragment count. The ground end first verifies the received data frame's check fields. If verification fails but error correction succeeds, it is marked as usable; if error correction fails, a retransmission is requested or missing fragments are located according to interleaving rules. When a discontinuous sequence number is detected, the ground end initiates a sliding reassembly window to wait for and fill in the missing sequence number; the window size is preferably 32 to 64 frames. When the underground end recovers from a power outage, it continues to output frames using the last "checkpoint frame" in the buffer and its sequence number, without restarting the acquisition process. To avoid ambiguity, "robust transmission preprocessing" in this embodiment refers to the interleaving and buffering strategies performed before transmission to enhance interference resistance and recoverability. A "checkpoint frame" refers to a periodically inserted lightweight frame used only for retransmission alignment (the period can be once every 20 frames). Its function is to provide a recovery anchor point after link interruption, thereby ensuring continuous uplink and complete reassembly of data under high temperature, high pressure, and strong disturbance environments.

[0057] The wellhead transmission and power supply subsystem of this embodiment adopts a "hybrid power supply and communication architecture," which integrates two sets of power supply and communication channels—one using cable physical media and the other using fiber optic physical media—within the same cabinet. These channels can operate independently or in combination. The cable channel injects stable power into the well via an isolated DC power supply, with the output voltage adjustable between 24 and 300 ohms. It features soft-start, current limiting, overvoltage, surge, and leakage protection. The fiber optic channel completes physical layer transmission and reception using standard optical modules. For communication, the cable channel preferably uses differential baseband or carrier modulation, while the fiber optic channel preferably uses Ethernet transmission and reception. The system incorporates an "adaptive bit rate" and a "selective retransmission mechanism" in the uplink. The "adaptive bitrate" refers to the automatic switching between preset rate levels based on near-end statistics of bit errors and packet loss. The cable channel offers four rates: 256, 512, 1024, and 2048 kilobits per second, while the fiber optic channel offers three rates: 10, 50, and 100 megabits per second. The criterion is the error ratio of the most recent 100 frames within a rolling window. When the error ratio is greater than 5, the rate drops by one level; when the error ratio is less than 1 for 10 consecutive windows, the rate increases by one level. The switching process maintains the transmission buffer and prevents data loss during reassembly. The "selective retransmission mechanism" means that the ground end initiates retransmission requests only for missing or failed frames based on sequence numbers and acknowledgment bitmaps. The sliding window size is 32-64 frames, and retransmission has higher priority than new frame transmission. When both cable and fiber optic connections are available simultaneously, the system operates according to a "primary channel in operation, backup channel hot standby" strategy. If the primary channel experiences three consecutive rate drops or a link interruption, it switches to the backup channel and automatically switches back after the primary channel recovers. To avoid ambiguity in terminology, in this embodiment, "adaptive bit rate" aims to dynamically balance interference resistance and throughput to ensure stable uplink under high temperature, high pressure and strong interference conditions, and "selective retransmission mechanism" aims to repair errors and maintain continuous sequence with minimal bandwidth overhead. The above functions are configured in the cabinet through a visual parameter page. Key parameters include rate level, window length, down-rate and up-rate thresholds, window size and switching conditions. Typical values ​​have been given in the aforementioned range and can be directly implemented.

[0058] Furthermore, in this embodiment, the ground digital processing and collaborative analysis subsystem introduces operating conditions and physical constraints when performing cross-parameter consistency verification. Through built-in mass conservation, energy conservation, and flow continuity models, it jointly verifies parameters such as temperature, pressure, flow rate, and electrical properties. The system first automatically establishes a current logging operating condition model based on wellhead flow rate, inlet / outlet temperature difference, and well section pressure distribution collected from the ground, dividing the well section into several depth units. Within each unit, fluid density and specific heat capacity are inferred from temperature and pressure, thereby calculating theoretical flow rate and energy transfer values. Subsequently, the system compares the theoretical calculated values ​​with the downhole measured values ​​unit by unit. When the deviation exceeds a set threshold (e.g., mass difference exceeding 2%, energy difference exceeding 3%), the unit is marked as a region of inconsistent physical constraints, and an automatic correction process is triggered to adjust the confidence level or interpolate the abnormal parameters.

[0059] To avoid ambiguity in terminology, in this embodiment, "operating condition constraints" refer to the computational boundary conditions established by combining the temperature, pressure, flow rate, and wellhead fluid characteristics of the geothermal well's operating state, used to limit the physically feasible range between parameters; "physical constraints" refer to the multi-parameter balance relationship constructed based on the principles of mass conservation, energy conservation, and flow continuity, whose function is to determine whether each parameter matches within the theoretical physical range. This design ensures that the system can maintain the consistency and reliability of results even under multi-source data noise or local measurement anomalies, thereby achieving robust collaborative analysis across parameters and well sections.

[0060] Corresponding to the above system, this embodiment also provides an intelligent analysis method for a high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system, applied to the above logging system. The method includes:

[0061] Step 100: Under a unified clock and a unified depth reference, the downhole logging subsystem samples temperature, pressure, flow rate and electrical parameters in parallel to obtain the sampling results;

[0062] Step 200: The sampling results are time-stamped and depth-stamped, anomaly removal and error correction coding are performed, and downhole data frames are generated;

[0063] Step 300: Continuously forward the downhole data frames to the surface through the uplink of the wellhead transmission and power supply subsystem to obtain uplink data packets;

[0064] Step 400: Receive and decode the uplink data packets using the terrestrial digital processing and collaborative analysis subsystem, recover the time stamps and depth stamps, and form the original dataset;

[0065] Step 500: Based on a unified clock and a unified depth benchmark, perform time-scale correction and registration within the same well section on the original dataset to obtain an aligned dataset;

[0066] Step 600: Based on at least one of the constraints of mass conservation, energy conservation, or flow continuity, perform consistency verification and quality identification on the aligned dataset, and output the dataset with quality identification;

[0067] Step 700: Under the constraints and quality label conditions, perform a collaborative inversion on the dataset with quality label to output stratified temperature-pressure flow characteristics, permeability characterization, and wellbore integrity index, collectively referred to as stratified indexes;

[0068] Step 800: Generate alarms and dispatch instructions based on the hierarchical indicators, and output them to the field execution terminal through a standardized interface.

[0069] Specifically, the method in this embodiment is run on the aforementioned logging system. For steps 100 to 500: the unified clock and depth reference unit issues parallel sampling triggers for four types of parameters—temperature, pressure, flow rate, and electrical properties—with a time resolution of 1 millisecond and a depth resolution of 1 centimeter. The sampling frequency is set to 1 to 10 times per second depending on the well section conditions. Immediately after sampling, the downhole edge acquisition and encoding unit writes a time stamp and depth stamp for each record and performs anomaly removal (out-of-limit removal, abrupt change smoothing, and missing data compensation) and error control (cyclic redundancy check or forward error correction). The data is then encapsulated into a downhole data frame, containing a time stamp, depth stamp, parameter data segment, integrity check segment, and frame sequence number. In step 300, the data frame is continuously transmitted upstream through the wellhead transmission and power supply subsystem. The link supports cable or fiber optic physical media, and adaptive bit rate and selective retransmission jointly ensure continuous transmission in interference scenarios. After receiving the data at the ground end, deduplication and error correction are performed according to the frame sequence number and check segment, and then the time stamp and depth stamp are decoded to generate the original dataset. Subsequently, using the ground depth as the primary reference, consistency checks and depth fine-tuning were performed by combining the winch encoder curve, downhole attitude calculation trajectory, and pressure-converted depth. The time axis was then drifted back and linearly interpolated according to the first frame time synchronization pulse and subsequent frame time markers to complete time scale correction and registration within the same well section, and an aligned dataset was output.

[0070] For steps 600 to 800: the ground digital processing and collaborative analysis subsystem calls the operating conditions and physical constraints to perform cross-parameter consistency verification and quality identification on the aligned dataset. The quality identification threshold can be configured according to quality difference 2 and energy difference 3. The system writes qualified or unqualified identification and confidence score for each depth unit, forming a dataset with quality identification. Collaborative inversion jointly obtains stratified temperature, pressure and flow characteristics, permeability characterization and wellbore integrity index under this dataset and operating condition boundary conditions. The output is a hierarchical index, including the temperature profile, pressure gradient, flow distribution, equivalent permeability and casing integrity score of each well section, with time and depth references for easy traceability. The system performs threshold matching and action mapping in the rule base according to the hierarchical index, generating alarms and dispatch instructions, including the execution object, target value, execution time limit and effective conditions. The instructions are output to the field execution terminal through a standardized interface. In this embodiment, the standardized interface refers to a message interface that conforms to the Ethernet or fieldbus communication specification, supporting instruction receipt and status feedback. The execution receipt and corresponding working condition data are archived synchronously, serving as the adaptive update basis for subsequent registration and collaborative inversion within the same well section, forming a closed-loop process of "sampling—framing—transmission—registration—verification—inversion—command—feedback".

[0071] Preferably, it further includes:

[0072] Step 900: Collect the execution feedback and corresponding operating condition data of the alarm and dispatch instructions, form a feedback record, and archive the feedback record with the alignment dataset for adaptive updates of registration and collaborative inversion in the same well section.

[0073] Optionally, after completing the alarm and dispatch command output, this embodiment further executes step 900 to achieve closed-loop feedback and adaptive model update. The ground digital processing and collaborative analysis subsystem receives execution feedback information from the field execution terminal in real time through a standardized interface, including command execution status, execution time, response delay, target achievement degree, and working condition data such as wellhead temperature, pressure, and flow rate changes after execution. The system automatically generates feedback records while receiving feedback, each record containing a command identifier, execution timestamp, execution result, and corresponding working condition parameters. After integrity verification, the feedback records are stored in the ground database and associated with the aligned dataset of the same batch according to well segment number, time stamp, and depth stamp, achieving a one-to-one correspondence between data and actions. In this embodiment, the so-called "feedback record" refers to a structured data set collected and verified after command execution. Its function is to reflect the effect of command execution and its dynamic impact on downhole working conditions, providing a basis for subsequent model correction.

[0074] After archiving the feedback records, the system automatically invokes the adaptive update module to iteratively adjust the registration and collaborative inversion models for the same well section. This module corrects physical constraint parameters and weighting factors based on actual operating condition changes in the feedback records, such as adjusting the differential pressure response coefficient to a new range or updating the heat transfer efficiency parameter. When the operating condition deviation is detected to be less than 2% after multiple consecutive executions, the system automatically increases the confidence level of the model version and solidifies the parameters. When the feedback records display alarms or the adjustment instructions fail to restore the operating conditions to normal, the system triggers a retraining mechanism to recalculate the feature weights for that well section. The updated model is automatically loaded in the next logging cycle, achieving a closed-loop iteration from logging data acquisition, analysis, control to feedback learning. This design ensures that the model self-calibrates and self-optimizes under real production data over a long period, thereby improving the accuracy and stability of geothermal well operation and control.

[0075] Preferably, based on at least one constraint of mass conservation, energy conservation, or flow continuity, the aligned dataset is subjected to consistency verification and quality labeling, and a dataset with quality labeling is output, including:

[0076] To align the dataset at adjacent depth sampling points Depth cells are formed, and discrete residuals are established according to the mass conservation principle, using the following formula: ;in, For depth position Fluid density at that location; For depth position Fluid density at that location; This refers to the effective flow cross-sectional area of ​​the well section; For depth position The average flow velocity at that location; For depth position The average flow velocity at that location; The overall compressibility coefficient of the fluid and the formation medium; The depth spacing between adjacent sampling points; For depth position Pressure at the location; For depth position Pressure at the location; The time sampling interval for aligning the dataset; This represents the mass-conserved residual for the depth element.

[0077] right Error propagation is performed to obtain the residual standard deviation, using the following formula: ;in, The standard deviation of the residuals; The equivalent standard deviation of density converted from temperature and pressure; The standard deviation of flow rate converted to flow velocity; This represents the standard deviation of the pressure measurement.

[0078] Calculate the standardized residuals and assign quality labels based on the standardized residuals, using the following formula: ;in, For standardized residuals; when The depth cell is marked as "qualified" when... The result is marked as "unqualified" and written into the dataset with quality labels;

[0079] For both "qualified" and "unqualified" depth cells, a confidence score is output simultaneously, using the following formula: ;in, The confidence score is based on the Gaussian assumption.

[0080] Furthermore, in this embodiment, the aligned dataset is used to form "depth units" (referring to the smallest calculation interval consisting of two adjacent depth positions and their corresponding times, used to ensure spatial and temporal consistency) at adjacent depth sampling points. For each depth unit, the residual of the unit is calculated according to the aforementioned mass conservation discrete residual formula; density is taken from the state equation conversion table or experimental calibration table corresponding to temperature and pressure; the effective flow cross-sectional area of ​​the well section is taken from the completion structure and logging section diameter; the average flow velocity is obtained from the flow rate conversion; the total compressibility coefficient is taken from the field calibration value of the formation and fluid or the block empirical value; the depth spacing comes from the depth marker; and the pressure and time interval come from the original fields of the aligned dataset. After performing dimensional uniformity checks and outlier masking on all input quantities, the system outputs the residuals unit by unit and writes them to a temporary result table, with fields including the upper depth boundary, lower depth boundary, time marker, and residual value.

[0081] Secondly, in this embodiment, the residual standard deviation is calculated according to the aforementioned error propagation formula. The density uncertainty comes from the combined uncertainty of the temperature and pressure sensing chains, the velocity uncertainty comes from the combined uncertainty of the flow sensing chain, and the pressure uncertainty comes from the calibration results of the pressure sensing chain. Each uncertainty is given an initial value under ground calibration conditions and is automatically corrected on-site according to the temperature and pressure drift curves. The system calculates the standardized residuals accordingly and completes quality labeling using threshold rules: when the standardized residual is no greater than 3, it is labeled as "qualified," and when it is greater than 3, it is labeled as "unqualified." At the same time, the labeling results, along with the time stamp and the upper and lower depth boundaries, are written into the "dataset with quality label." To avoid ambiguity, the "dataset with quality label" refers to the structured data set formed by adding a quality label and scoring field to each depth unit on the basis of the aligned dataset, which is used for subsequent collaborative inversion. Its purpose is to provide traceable quality control information.

[0082] Finally, this embodiment generates a confidence score for each depth unit according to the aforementioned scoring formula, and archives it along with the quality label for weight reference in collaborative inversion and display of result credibility. An example is provided: the depth unit ranges from 2500.00 to 2500.10, with a time interval of 1; the densities are 900 and 905 kg / m³, the flow cross-sectional area is 0.01 m², the average flow velocities are 0.30 and 0.28 m / s, the total compressibility factor is 0.00000001 Pa, and the pressures are 30.0 and 30.2 MPa. The residual for this depth unit, calculated using the aforementioned formula, is approximately 0.166 kg / s, the standard deviation of the residual is approximately 0.067 kg / s, the standardized residual is approximately 2.48, and the confidence score is approximately 0.047. Based on the threshold rule, this unit is marked as "qualified," and the "qualified" label and the score field are written into the dataset with the quality label for subsequent collaborative inversion and result traceability.

[0083] Preferably, alarm and dispatch instructions are generated based on the hierarchical indicators and output to the field execution terminal through a standardized interface, including:

[0084] The set of hierarchical indicators is parsed, and the mapping from indicators to actions is completed based on a preset threshold table and rule base, forming instruction candidates and priorities;

[0085] According to the priority, the conflict resolution and merging of the instruction candidates are performed to generate alarm and dispatch instructions, and each instruction is accompanied by the execution object, target value, execution time limit and effective conditions.

[0086] The alarm and dispatch instructions are encapsulated into an instruction message, with a timestamp and sequence number added. Integrity verification and signature verification are performed to obtain the message to be sent.

[0087] The message to be sent is output to the field execution terminal through a standardized interface, and the execution confirmation receipt is received and associated with the corresponding level indicators for archiving.

[0088] Specifically, in this embodiment, an index parsing module and a rule base are set up in the ground digital processing and collaborative analysis subsystem to perform parsing and matching on the hierarchical index set output by collaborative inversion: This embodiment reads the numerical range and changing trend of each index from the threshold table, maps situations such as temperature gradient exceeding the limit, pressure gradient abnormality, flow distribution deviation, and wellbore integrity decline into action templates, generates instruction candidates, and determines the priority (high, medium, low) based on the severity level and time sensitivity to ensure that high-risk scenarios are handled first.

[0089] This embodiment resolves and merges conflicting command candidates within the command generation module. When multiple requirements exist for the same execution object, this embodiment retains the highest priority command or performs numerical coordination according to a priority strategy, forming a unique alarm and dispatch command. Each command is accompanied by the execution object (e.g., valve, pump, heat exchange unit), target value (e.g., set flow rate or pressure), execution time limit (e.g., response within 30 seconds), and activation condition (e.g., triggering if continuous deviation exceeds 5 minutes). Subsequently, this embodiment encapsulates the message, adds a timestamp and sequence number to the command message, and completes integrity verification and digital signature verification to obtain the message to be sent and records the generation log for traceability.

[0090] This embodiment outputs the message to be sent to the field execution terminal through a standardized interface and manages the receipt archiving: This embodiment uses an interface that conforms to industrial communication protocols (such as Ethernet or fieldbus) to complete downlink transmission and uplink confirmation. The field execution terminal returns a confirmation receipt containing the instruction identifier, execution time, execution status, and result parameters. This embodiment associates the receipt with the corresponding level indicators one by one and archives them as the data basis for subsequent threshold optimization, rule revision, and model adaptive update, forming a closed loop of the entire process of "indicator parsing - instruction generation - message distribution - receipt archiving".

[0091] The beneficial effects of this invention are as follows:

[0092] (1) By constructing a unified clock and a unified depth benchmark downhole, this invention achieves synchronous sampling and time and depth dual marking of multiple parameters such as temperature, pressure, flow rate and electrical properties, so that each parameter can be directly compared at the same time scale and the same depth. This solves the problems of asynchronous time, depth drift and alignment difficulties in existing geothermal logging data, and greatly improves the accuracy of parameter comparison and data consistency within the well section.

[0093] (2) The present invention adopts a high temperature and high pressure resistant packaging and heat insulation and vibration isolation structure to ensure that the downhole multi-parameter sensor string and edge acquisition unit can operate stably for a long time in an environment of 150℃ to 180℃ and 70MPa to 80MPa. It overcomes the defects of traditional logging tools in deep high temperature and high pressure environment, such as signal drift, distortion or damage, and realizes reliable continuous measurement in deep downhole environment.

[0094] (3) The edge acquisition and encoding unit of the present invention performs error control and robust transmission preprocessing downhole. Combined with cyclic redundancy check, forward error correction, interleaving and data buffering technology, and with the hybrid power supply architecture, adaptive code rate and selective retransmission mechanism of the wellhead transmission and power supply subsystem, it effectively reduces data packet loss and discontinuity under high temperature, high pressure and strong interference conditions, and ensures the stability and reliability of the uplink data link.

[0095] (4) The ground digital processing and collaborative analysis subsystem of the present invention introduces working conditions and physical constraints, and performs cross-parameter consistency verification and collaborative inversion through the principles of mass conservation, energy conservation and flow continuity. It automatically generates layered temperature and pressure flow characteristics, permeability characterization and wellbore integrity index, realizes physical consistency verification and high-precision comprehensive interpretation of multi-source parameters, and significantly improves the intelligent level of geothermal well analysis.

[0096] (5) This invention uses an automatic mapping mechanism from hierarchical indicators to alarms and dispatch instructions, and uses a standardized interface to achieve bidirectional communication with the field execution end. Combined with execution feedback and model adaptive updates, it forms a closed-loop operation mode of "logging-analysis-control-feedback". This not only realizes real-time risk warning and production optimization adjustment, but also realizes the continuous optimization and self-learning ability of the model under actual working conditions.

[0097] The various embodiments in this specification are described in a progressive manner, with each embodiment focusing on the differences from other embodiments. The same or similar parts between the various embodiments can be referred to each other.

[0098] This document uses specific examples to illustrate the principles and implementation methods of the present invention. The descriptions of the above embodiments are only for the purpose of helping to understand the method and core ideas of the present invention. Furthermore, those skilled in the art will recognize that, based on the ideas of the present invention, there will be changes in the specific implementation methods and application scope. Therefore, the content of this specification should not be construed as a limitation of the present invention.

Claims

1. A high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system, characterized in that, include: The downhole logging subsystem consists of a high-temperature and high-pressure resistant encapsulated multi-parameter sensor string, a unified clock and depth reference unit, and an edge acquisition and encoding unit. The multi-parameter sensor string is used to sample temperature, pressure, flow rate, and electrical data in parallel under the same time scale and the same depth reference to obtain the sampling results. The edge acquisition and encoding unit is used to perform time and depth marking, anomaly removal and error correction encoding on the sampling results to generate downhole data frames; The wellhead transmission and power supply subsystem is electrically connected to the downhole logging subsystem and is used to provide steady-state power supply and uplink to continuously forward the downhole data frames to the surface in an anti-interference manner. The surface digital processing and collaborative analysis subsystem is used to sequentially execute the reception and decoding of the downhole data frames, time-scale correction and registration within the same well section, cross-parameter consistency verification and collaborative inversion under operating condition constraints, output stratified temperature, pressure and flow characteristics, permeability characterization and wellbore integrity indicators, and generate alarm and dispatch instructions for production.

2. The high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system according to claim 1, characterized in that, The downhole logging subsystem employs a high-temperature and high-pressure resistant encapsulation with a metal seal and thermal insulation and vibration isolation structure. The multi-parameter sensor string and the edge acquisition and encoding unit operate continuously under conditions where the upper limit of temperature resistance is not less than 150℃ and the upper limit of pressure resistance is not less than 70MPa, and the stability of the unified clock and depth reference unit is maintained within the full temperature and pressure range to meet the synchronous sampling requirements.

3. The high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system according to claim 1, characterized in that, The unified clock and depth reference unit includes a high-stability clock and a depth measurement combination. The high-stability clock is used to provide the same time scale for parallel sampling and time stamping. The depth measurement combination is used to fuse with the ground depth reference to form the same depth reference. The ground digital processing and collaborative analysis subsystem performs time scale correction and registration within the same well section on the uplink downhole data frames to achieve reliable comparison of multiple parameters within the same well section.

4. The high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system according to claim 1, characterized in that, The edge acquisition and encoding unit further performs error control and robust transmission preprocessing when generating downhole data frames; the error control includes one of cyclic redundancy check and forward error correction; the robust transmission preprocessing includes one of interleaving or data buffering to support breakpoint resume and complete reassembly after data packet loss.

5. The high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system according to claim 1, characterized in that, The wellhead transmission and power supply subsystem is a hybrid power supply and communication architecture that supports at least one physical medium, either cable or optical fiber. The wellhead transmission and power supply subsystem is equipped with an uplink adaptive bit rate and selective retransmission mechanism.

6. The high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system according to claim 1, characterized in that, The ground digital processing and collaborative analysis subsystem introduces constraints related to operating conditions and physics during cross-parameter consistency verification; these constraints include at least one of mass conservation, energy conservation, or flow continuity.

7. An intelligent analysis method for a high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system, characterized in that, The method, applied to the logging system according to any one of claims 1 to 6, comprises: Under a unified clock and a unified depth benchmark, the downhole logging subsystem samples temperature, pressure, flow rate, and electrical parameters in parallel to obtain the sampling results; The sampling results are time-stamped and depth-stamped, and anomaly removal and error correction coding are performed to generate downhole data frames; The uplink data frame from the wellhead transmission and power supply subsystem is continuously forwarded to the surface to obtain uplink data packets. The uplink data packets are received and decoded using the terrestrial digital processing and collaborative analysis subsystem to recover the time stamps and depth stamps, forming the original dataset. Based on a unified clock and a unified depth benchmark, time-scale correction and registration within the same well section are performed on the original dataset to obtain an aligned dataset. Based on at least one of the constraints of mass conservation, energy conservation, or flow continuity, the aligned dataset is subjected to consistency verification and quality labeling, and a dataset with quality labeling is output. Under the constraints and quality label conditions, the dataset with quality label is subjected to collaborative inversion to output stratified temperature-pressure-flow characteristics, permeability characterization and wellbore integrity index, collectively referred to as stratified index; Alarms and dispatch instructions are generated based on the hierarchical indicators and output to the field execution terminal through a standardized interface.

8. The intelligent analysis method for the high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system according to claim 7, characterized in that, Also includes: The execution feedback of the alarm and dispatch commands and the corresponding operating condition data are collected to form a feedback record. The feedback record is then associated with the alignment dataset and archived for adaptive updates of registration and collaborative inversion within the same well section.

9. The intelligent analysis method for the high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system according to claim 7, characterized in that, Based on at least one constraint of mass conservation, energy conservation, or flow continuity, the aligned dataset is subjected to consistency verification and quality labeling, and a dataset with quality labeling is output, including: To align the dataset at adjacent depth sampling points Depth cells are formed, and discrete residuals are established according to the mass conservation principle, using the following formula: ;in, For depth position Fluid density at that location; For depth position Fluid density at that location; This refers to the effective flow cross-sectional area of ​​the well section; For depth position The average flow velocity at that location; For depth position The average flow velocity at that location; The overall compressibility coefficient of the fluid and the formation medium; The depth spacing between adjacent sampling points; For depth position Pressure at the location; For depth position Pressure at the location; The time sampling interval for aligning the dataset; This represents the mass-conserved residual for the depth element. right Error propagation is performed to obtain the residual standard deviation, using the following formula: ;in, The standard deviation of the residuals; The equivalent standard deviation of density converted from temperature and pressure; The standard deviation of flow rate converted to flow velocity; This represents the standard deviation of the pressure measurement. Calculate the standardized residuals and assign quality labels based on the standardized residuals, using the following formula: ;in, For standardized residuals; when The depth cell is marked as "qualified" when... The result is marked as "unqualified" and written into the dataset with quality labels; For both "qualified" and "unqualified" depth cells, a confidence score is output simultaneously, using the following formula: ;in, The confidence score is based on the Gaussian assumption.

10. The intelligent analysis method for the high-temperature and high-pressure resistant digital geothermal multi-parameter collaborative logging system according to claim 7, characterized in that, Based on the aforementioned hierarchical indicators, alarms and dispatch instructions are generated and output to the field execution terminal through a standardized interface, including: The set of hierarchical indicators is parsed, and the mapping from indicators to actions is completed based on a preset threshold table and rule base, forming instruction candidates and priorities; According to the priority, the conflict resolution and merging of the instruction candidates are performed to generate alarm and dispatch instructions, and each instruction is accompanied by the execution object, target value, execution time limit and effective conditions. The alarm and dispatch instructions are encapsulated into an instruction message, with a timestamp and sequence number added. Integrity verification and signature verification are performed to obtain the message to be sent. The message to be sent is output to the field execution terminal through a standardized interface, and the execution confirmation receipt is received and associated with the corresponding level indicators for archiving.

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