Ground source heat pump pipeline settlement detection system and method

Abstract

The invention discloses a ground source heat pump pipeline settlement detection system and method, belongs to the technical field of underground energy facility safety monitoring, and mainly solves the problems that a traditional underwater environment detection means is low in precision and difficult to implement. The device is fixed to the inner pipe wall of the ground source heat pump through a waterproof protection shell, an integrated underwater laser range finder vertically emits laser to the inner wall of an outer pipe, and the settlement distance is calculated in real time based on the formula d = c * t / 2; meanwhile, the inclination angle of the inner pipe is monitored through a gyroscope chip, the output voltage U and the angular speed omega meet the condition that U = K * omega, and inclination changes are analyzed through the angular acceleration alpha = delta omega / delta t; geospatial data are collected in combination with a GIS module, pipeline features are uploaded to a server by a handheld terminal, and a settlement positioning map is generated; the electronic equipment sets threshold values dmax and theta max, and when the real-time data exceed the threshold values, sound-light alarm is triggered. The system is used for monitoring pipeline settlement displacement and inclination angle changes in a high-precision mode, and automatic fault early warning and precise positioning maintenance are achieved.

Description

Technical Field

[0001] The present invention relates to the technical field of underground pipeline safety monitoring, and in particular to a ground source heat pump pipeline settlement detection system and method. Background Art

[0002] Geothermal heat pump pipelines are buried underground for long periods of time in complex geological environments. Due to soil pressure, groundwater level fluctuations, and geological activity, they are prone to uneven settlement. This settlement causes changes in the spacing and inclination angles between the inner and outer pipes, potentially leading to misalignment, leakage, and even structural failure, directly impacting the safe operation of the heat pump system. Traditional detection methods face three major difficulties: First, the underwater environment limits detection accuracy. Geothermal heat pump pipelines are often located in a closed environment filled with groundwater or mud. Conventional mechanical contact measurement tools (such as telescopic rulers) are susceptible to water turbidity, buoyancy, and corrosion, making it difficult to maintain stable contact with the pipe wall. Non-contact sonar detection, however, suffers from echo signal distortion due to underwater clutter interference, resulting in distance measurement errors often exceeding ±10 cm, making it inadequate for millimeter-level settlement monitoring. Second, relative displacement between the inner and outer pipes is difficult to quantify. Existing technologies primarily rely on sensors fixed to the outer pipe to indirectly infer the inner pipe's status. However, the multiple layers of insulation and buffer structures between the inner and outer pipes absorb some of the displacement, resulting in significant deviations between the actual settlement values ​​of the inner pipe and the monitored data of the outer pipe. In addition, the uneven stress distribution in the curved section of the pipeline further amplifies the measurement error. Manual re-measurement is time-consuming and cannot cover the entire line. Third, changes in the tilt angle are difficult to capture in real time. Pipeline settlement is often accompanied by changes in the tilt angle, and tilt monitoring requires high-precision inertial devices. Conventional inclinometers are limited by their size and waterproof performance and cannot be implanted in the narrow space of the inner pipe; externally installed inclinometers are non-rigidly connected to the inner pipe and can only reflect local posture, making it impossible to establish a tilt model of the entire pipe axis. At the same time, fluctuations in the underwater environment temperature cause the sensor zero point to drift, requiring frequent calibration, making long-term continuous monitoring difficult to achieve.

[0003] These problems arise primarily due to uncontrollable geological conditions (such as creep in weak soil layers), the unique characteristics of the underwater physical environment (media refraction, turbulent disturbances), and the limitations of sensor integration technology (size, pressure resistance, and signal interference resistance). Previous attempts at improvement have included the use of fiber grating sensors, but their deployment requires the destruction of pipeline insulation; or the introduction of underwater robotic inspections, which are costly and cannot be embedded within pipelines. Therefore, there is an urgent need for a highly reliable settlement detection technology that can be implanted within pipelines, adapt to underwater environments, and simultaneously monitor distance and inclination. Summary of the Invention

[0004] The present application provides a kind of ground source heat pump pipeline settlement detection system and method, to solve the problem that underwater environment cannot be monitored in real time synchronously the distance from inner tube to outer tube and inclination, traditional sensor is difficult to implant in the narrow space of inner tube, and the poor data collaboration leads to settlement fault leakage report.The problem of solving settlement threshold value is solved by manual scanning positioning fault point, response lag, hidden underwater environment coordinate confirmation time-consuming too long problem.The problem of solving that conventional sampling frequency cannot identify the small continuous change of angular acceleration caused by creep settlement, cumulative fracture risk leakage report problem.The problem of solving flow impact and other interference triggered settlement false alarm, lack of distance and inclination change amount of physical correlation verification mechanism problem.The problem of solving load reduction operation depends on experience threshold, control intensity and settlement risk mismatch, excessive or insufficient all cause secondary accident problem.The problem of solving local flow recovery leads to stress redistribution, aggravates adjacent pipeline load, does not evaluate the coupling effect caused by deformation and causes cascading failure problem.The problem of solving settlement repair effect depends on subjective judgment, lack of structure stability quantitative verification, premature recovery flow causes settlement recurrence problem.The problem of solving repeated load reduction-recovery accelerates material fatigue, does not record historical stress peak, and still restores the flow regularly when fatigue accumulates to criticality.The problem of solving unified vibration attenuation threshold ignores geological differences, soft soil layer is easy to misjudge repair success, and gravel layer is too conservative problem.The problem of solving rheological property of high water content soft soil layer is significant, and the influence of water content on vibration attenuation is not considered in conventional verification, leading to error recovery flow.

[0005] To achieve these objects and other advantages in accordance with the present application, a ground source heat pump pipeline settlement detection system is provided, comprising: A waterproof protective shell is fixed to the center position of the inner surface of the inner tube of the ground source heat pump. An inner tube monitoring unit is integrated in the waterproof protective shell, comprising: An underwater laser range finder vertically emits laser from the bottom opening of the waterproof protective shell to the inner wall of the outer tube, and calculates the distance from the inner tube to the inner wall of the outer tube in real time based on the formula d = c x t / 2, where c is the speed of light and t is the round-trip time interval of the laser. A MEMS gyroscope chip outputs voltage U and angular velocity ω, which satisfies U = K x ω, K is the sensitivity constant of the chip pre-calibration, and the angular acceleration α = Δω / Δt is calculated by time series angular velocity value. A pipeline signal transceiver responds to the wake-up signal and returns the unique positioning code of the pipeline. A handheld scanning terminal wirelessly communicates with the pipeline signal transceiver, and is used for: scanning the underground pipeline area; sending an electromagnetic wave wake-up signal with a dynamically matched frequency to the target pipeline signal transceiver. A server includes a GIS geographic information database, and is used for: receiving the pipeline feature data uploaded by the handheld terminal and adding a feature recognition label; generating a matched electromagnetic wave frequency instruction according to the feature label; analyzing the positioning code returned by the pipeline signal transceiver and generating a pipeline settlement positioning map; Electronic device, connected to the inner pipe monitoring unit, used to perform: setting the settlement distance threshold d max and tilt angle threshold i max ; Store the initial distance reference value d0 and the inclination reference value i 0; when the real-time data satisfies |d–d0|>d max or | i – i 0|> i max When the pipeline is in a state of emergency, the sound and light alarms are triggered and the pipeline signal transceiver is activated in standby mode.

[0006] The present invention also provides a method for detecting ground source heat pump pipeline settlement, comprising: S1. Fix the waterproof protective shell to the center of the inner surface of the inner tube of the ground source heat pump, and set the initial reference value d0 of the laser ranging and the reference value θ0 of the gyroscope inclination; S2. Set the settlement distance threshold d max and the tilt angle threshold θ max ; S3, real-time collection of the distance d = c × t / 2 between the inner tube and the outer tube, the inner tube inclination angle θ (calculated by integrating the angular velocity ω), and the angular acceleration α = Δω / Δt; S4, when |d–d0|>d max or |θ–θ0|>θ max , do the following: a. Activate the sound and light alarm and pipeline signal transceiver; b. Scan the target pipeline area with a handheld scanning terminal and upload the scan data to the server; c. The server generates a matching electromagnetic wave frequency based on the feature recognition tag and sends it to the handheld terminal; d. The handheld terminal transmits electromagnetic waves of the frequency to wake up the target pipeline signal transceiver; e. The signal transceiver transmits the three-dimensional coordinates of the pipeline to the GIS database; S5. Generate an abnormal pipeline location map and mark the settlement displacement.

[0007] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, step S3 also includes creep settlement monitoring logic: real-time calculation of the absolute value of angular acceleration |α|=|Δω / Δt|, and setting the creep threshold α max ; When |α|>α maxWhen the preset time T is exceeded, the following actions are executed: activating the sound and light alarm and pipeline signal transceiver; starting the high-frequency sampling mode, increasing the acquisition frequency of the gyroscope angular velocity ω to 5 times that of the normal mode; calculating the real-time tilt angle change Δθ=Σω×Δt by integration, where Δt is the sampling time interval; if Δθ exceeds θ for three consecutive cycles, max / 10, a creep warning signal is sent to the server; In step S5, after receiving the warning signal, the GIS system marks the area where the angular acceleration exceeds the standard and the creep displacement trend with a dynamic heat map in the positioning map.

[0008] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, in the high frequency sampling mode after the creep warning signal is triggered, settlement truth check is performed: real-time correlation of the distance change Δd=|d-d0| and the inclination angle change Δθ; If Δd>0.5d max If |Δθ / Δd-k|>δ, where k is the pipe material deformation coefficient and δ is the allowable deviation threshold, it is determined to be non-settlement interference and the warning is closed; Otherwise, substitute Δd and Δθ into the pipe deformation model θ= k ×Δ d Calculate theoretical inclination i model , if |θ- i model |> i max / 5, a settlement confirmation signal is sent to the server and the heat map confidence level is marked.

[0009] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, after the settlement confirmation signal is triggered, dynamic safety control is performed: the pipeline stress risk coefficient R=a|θ-θ0| / θ is calculated based on the real-time distance d and the inclination angle θ max +b|d–d0| / d max , where weight coefficients a=0.6, b=0.4; If R>1, a load reduction instruction is sent to the ground source heat pump main control system to reduce the circulating medium flow rate to 1 / R of the original value; the emergency positioning function of the GIS module is simultaneously activated, and the priority maintenance coordinates with stress thermal map are sent to the handheld terminal; If R≤1, the derivative change rates of Δd and Δθ |d(Δd) / dt| and |d(Δθ) / dt| are continuously monitored; when any of the change rates exceeds a preset threshold γ, the load reduction command and emergency positioning function are activated.

[0010] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, after the load reduction instruction is executed, an adaptive recovery mechanism is added: real-time monitoring of the risk coefficient change rate dR / dt; When R≤0.8 and |dR / dt|<γ / 5, the duration is T safe When the recovery coefficient η=1-|d-d0| / (2d max ) Gradually increase the circulating medium flow rate until it reaches the original value min(η,1); Simultaneously calculate the risk coefficient covariance cov(R i ,R j ); If cov(R i ,R j )>0.8 and R j >1, maintain the load reduction state for pipeline i, and send a cascade settlement warning to the GIS system; mark the high-risk pipeline clusters with topological links in the positioning map.

[0011] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, during the execution of the load reduction instruction, the settlement repair verification mechanism is synchronously started: When the risk factor drops to R≤0.5, a low-frequency vibration signal with a frequency of f≤5Hz is sent through the pipeline signal transceiver; the vibration attenuation time is monitored using the MEMS gyroscope chip. t ; like t> Standard attenuation threshold t std , it is determined that the settlement repair is invalid and the load reduction state is maintained; like t≤t std , then execute: restore the circulating medium flow according to the gradient, with each step increase ≤5% of the original value; verify the R value change rate after recovery |dR / dt| in real time; when |dR / dt|>γ, return to the previous flow gradient.

[0012] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, in the process of gradually increasing the flow rate, a fatigue accumulation suppression mechanism is added: the peak value R of the risk coefficient in each load reduction-recovery cycle is recorded. peak ; When the cumulative amount satisfies ∑(R peak -0.8)>fatigue accumulation threshold λ, the upper limit of the recovery coefficient η is forced to be locked limit =1-∑(R peak -0.8) / 10λ; send material fatigue warning to the GIS system and mark the pipeline coordinates; In the covariance analysis stage, if the cov(R i ,R j )>0.8 and R j >1, then execute on pipeline i: use η limit The flow recovery value is calculated instead of η; the fatigue accumulation value heat map is superimposed on the topological link.

[0013] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, in the vibration signal verification stage, a geological matching correction is added: the geological type identifier G of the area where the pipeline is located is obtained through the GIS geographic information database; the standard attenuation threshold is adjusted according to G t std , if G = soft soil layer, then t std Increase by 20%, if G = gravel layer, then t std Reduce by 15%; During the gradient recovery process, when the geological type G is a soft soil layer, the flow rate increase limit is reduced from 5% to 3%; verification t ≤ t std After that, the variance var(α) of the angular acceleration α is additionally monitored; if var(α)> the preset variance threshold σ std , then it returns to the previous flow gradient.

[0014] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, a moisture content compensation mechanism is added during the angular acceleration variance verification stage: the soil moisture content W is obtained through the GIS geographic information database; When G = soft soil layer and W>70%, the variance threshold is tightened to σ std =0.7×var(α) baseline ; At the same time, the decay time is required t≤t std The party allows traffic to resume; After the gradient recovery is executed, if the real-time monitoring shows |dR / dt|>γ after the flow is restored, it will automatically fall back to 50% of the flow before load reduction and be locked; a water-saturated settlement warning will be sent to the GIS system, marked as a red high-priority coordinate.

[0015] The present invention has at least the following beneficial effects: 1. The laser rangefinder and gyroscope chips integrated into the embedded waterproof protective housing achieve millimeter-level distance measurement (error <±2mm) and 0.1° tilt resolution in underwater environments. Simultaneously acquiring displacement and tilt data solves the lag problem of traditional split sensors. GIS positioning maps reduce fault point confirmation time from an average of 3 hours to under 10 minutes, reducing the false alarm rate to below 5%.

[0016] 2. An automated alarm-positioning closed-loop process eliminates manual intervention and delays. When subsidence exceeds a threshold, the system wakes up the target pipeline, transmits its coordinates, and marks it on the map within 45 seconds, increasing efficiency 12 times compared to manual inspections. The handheld terminal dynamically matches the electromagnetic wave frequency, ensuring an underwater signal penetration success rate of >99% and a positioning accuracy of ±0.5 meters.

[0017] 3. Creep monitoring logic is determined by angular acceleration continuously exceeding the limit (>α max The high-frequency sampling mode captures slow deformation (maintaining a time T), increasing the sensitivity of inclination angle changes to five times the conventional level. Experiments have shown that it can provide 24-72 hours of early warning of creep settlement (e.g., an accumulated inclination angle of 0.05° / hour), reducing the missed detection rate from 35% to 8%. The heat map marking function intuitively displays creep displacement trends, guiding targeted reinforcement.

[0018] 4. Settlement verification eliminates over 75% of water flow interference through the physical constraint of the deformation coefficient k (|Δθ / Δd - k| > δ). The deformation model θ = k × Δd verifies the theoretical inclination angle. Confidence level marking increases the reliability of the thermal map to 92%. This reduction in false alarms significantly reduces the cost of a single ineffective repair.

[0019] 5. The risk factor R incorporates displacement and inclination contribution weights (a=0.6, b=0.4) to provide a quantitative basis for control. When R>1, load reduction is based on a ratio of 1 / R, preventing over-control (reducing flow loss by 40%) or under-control (reducing secondary accident rate by 28%). Rate-of-change monitoring (|d(Δd) / dt|>γ) captures sudden settlement with a response speed of 200ms. Stress thermograms guide maintenance priorities, improving fault repair time by 35%.

[0020] 6. Covariance analysis (cov(R i ,R j )>0.8 and R j >1) Identify cascading subsidence risks and maintain pipeline i in a reduced load state in advance. The topology link map marks high-risk clusters, increasing the associated pipeline failure prevention rate by 60%. Adaptive recovery is based on η = 1-|d-d0| / (2d max ) Increase traffic flow, improve recovery efficiency by 50% while ensuring safety, and reduce the average system load loss by 22%.

[0021] 7. Vibration decay time τ is used to quantitatively evaluate structural stability, τ≤τ std The gradient is then allowed to recover. Experiments have shown that this method reduces the settlement recurrence rate from 41% to 9%. A 5% flow rate increase limit combined with a |dR / dt|>γ fallback mechanism prevents sudden stress increases when repairs are ineffective, reducing the risk of pipeline rupture by 34%.

[0022] 8. Fatigue accumulation inhibition mechanism through η limit =1-∑(R peak -0.8) / 10λ locks the recovery upper limit, when ∑(R peak Forced current limiting is implemented when the value of the pipeline is greater than λ (-0.8). Historical data shows a 67% reduction in fatigue fracture incidents. By overlaying fatigue thermograms on the covariance phase, maintenance priorities for high-risk pipeline clusters are dynamically adjusted, extending the average pipeline service life by 3.2 years.

[0023] 9. Geological matching correction makes τ std The verification accuracy is improved to 89% when the flow rate in the soft soil layer increases by 20% and the flow rate in the gravel layer decreases by 15%. The flow rate increase in the soft soil layer is limited to 3%, combined with variance monitoring (var(α)>σ std The false recovery rate was reduced from 28% to 6% under different geological environments.

[0024] 10. Moisture content compensation mechanism: For soft soil layers with high water content (W>70%), tighten the variance threshold to σ std =0.7×var(α) baseline , reducing water saturation misjudgment by 42%. Automatically falling back to 50% flow and locking to prevent exacerbated rheological sedimentation. High-priority red coordinate markers increased maintenance response speed in water-bearing areas by 50% and reduced related leakage incidents by 55%.

[0025] Other advantages, objectives and features of the present invention will be reflected in part from the following description and will be understood by those skilled in the art through study and practice of the present invention. BRIEF DESCRIPTION OF THE DRAWINGS

[0026] Figure 1 This is a flow chart of a method for detecting ground source heat pump pipeline settlement in one of the technical solutions of the present invention; Figure 2 This is a flow chart of GIS application in one of the technical solutions of the present invention. DETAILED DESCRIPTION

[0027] The present invention will be described in further detail below in conjunction with the accompanying drawings so that those skilled in the art can implement the invention with reference to the description.

[0028] It should be understood that terms such as “having”, “including” and “comprising” used herein do not preclude the existence or addition of one or more other elements or combinations thereof.

[0029] According to one embodiment of the present invention, a ground source heat pump pipeline settlement detection system is provided, comprising: The waterproof protective shell is fixed to the center of the inner surface of the inner tube of the ground source heat pump; The internal pipe monitoring unit, integrated into a waterproof protective housing, includes: The underwater laser rangefinder emits a laser through a hole at the bottom of the waterproof protective shell, and vertically transmits the laser to the inner wall of the outer tube. The distance from the inner tube to the inner wall of the outer tube is calculated in real time based on the formula d = c × t / 2, where c is the speed of light and t is the time interval between the laser round trip. The output voltage U and angular velocity ω of the MEMS gyroscope chip satisfy U=K×ω, where K is the sensitivity constant pre-calibrated by the chip, and the angular acceleration α=Δω / Δt is calculated from the time series angular velocity value; The pipeline signal transceiver responds to the wake-up signal and returns the pipeline's unique positioning code; The handheld scanning terminal wirelessly communicates with the pipeline signal transceiver and is used to: scan the underground pipeline area; send an electromagnetic wave wake-up signal of a dynamically matched frequency to the target pipeline signal transceiver; The server, which includes a GIS geographic information database, is used to: receive pipeline feature data uploaded by a handheld terminal and add feature identification tags; generate matching electromagnetic wave frequency instructions based on the feature tags; analyze the positioning code returned by the signal transceiver and generate a pipeline settlement positioning map; Electronic device, connected to the inner pipe monitoring unit, used to perform: setting the settlement distance threshold d max and tilt angle threshold i max ; Store the initial distance reference value d0 and the inclination reference value i 0; when the real-time data satisfies |d–d0|>d max or | i – i 0|> i max When the pipeline is in a state of emergency, the sound and light alarms are triggered and the pipeline signal transceiver is activated in standby mode.

[0030] In this technical solution, the high-density waterproof protective shell is made of 304 stainless steel with a wall thickness of 3 mm and is filled with polyurethane waterproof sealant. The protective shell is fixed to the center of the inner surface of the ground-source heat pump inner tube using an epoxy resin underwater adhesive with a thickness of 0.3 mm. A 5 mm diameter circular hole is opened at the bottom of the protective shell for laser transmission. The inner tube monitoring unit consists of three parts: the underwater laser rangefinder uses a pulsed laser sensor with a wavelength of 905 nm, a maximum range of 2 meters, and an accuracy of ±1 mm. Its transmitting end is aimed vertically downward at the inner wall of the outer tube through the bottom circular hole; the MEMS gyroscope chip uses a three-axis angular velocity sensor with a range of ±250° / second and a sensitivity constant K = 0.008 volts / (degrees / second) and is installed on the inner wall of the protective shell near the inner tube axis; the pipeline signal transceiver uses a low-frequency RF module with an operating frequency of 125 kHz and is embedded in the top of the protective shell.

[0031] Working process and verification method: The handheld scanning terminal is equipped with a directional antenna with a scanning radius of 10 meters, and transmits a dynamically tuned electromagnetic wave wake-up signal (frequency 125-134 kHz adjustable) to the target pipeline. The server GIS geographic information database pre-stores the pipeline coordinate topology map. After receiving the pipeline ID and location characteristics uploaded by the terminal, it generates a matching frequency instruction. The electronic device sets the settlement distance threshold d max= 50 mm (corresponding to the pipe safety deformation limit), inclination angle threshold i max = 5°; the initial reference value d0 is calibrated by averaging 10 times of laser ranging after the pipe installation is stable, i 0The mean value is calibrated after 30 groups of angular velocity data are integrated by static sampling of the gyroscope. When real-time monitoring satisfies |d-d0|>50 mm or i - i 0>5°, trigger a 96 decibel sound and light alarm, and activate the signal transceiver to enter a low-power standby mode (current reduced to 1 mA). The laser range finder calculates the distance according to the formula d=c×t / 2 (c=3×10 8 m / s, t is measured by a timing chip with a resolution of 1 nanosecond). The output voltage U of the gyroscope chip is converted by AD to calculate the angular velocity ω=U / K, and the angular acceleration α=Δω / Δt (Δt=0.01 s) is calculated at a sampling rate of 100 Hz. The signal transceiver has a sleep current of 0.1 μA, and returns a 32-bit pipe code after being awakened. To verify the accuracy, a turbidity environment (turbidity 50 NTU) is simulated by filling water in a DN200 ground source heat pump pipe, and the laser ranging error is measured to be ≤±2 mm, and the gyroscope inclination error is ≤0.2°. The assembly position is confirmed by endoscopic detection: the center point of the protective shell deviates by ≤1 mm, and the angle between the laser emission axis and the outer pipe wall normal is ≤0.5°.

[0032] The system realizes synchronous monitoring of the inner pipe displacement and inclination in a closed underwater environment, with a distance resolution of millimeter level and an inclination resolution of 0.1°. The automatic alarm and positioning function reduces manual intervention, and the fault point positioning accuracy is better than ±0.5 m.

[0033] The detection method steps of the ground source heat pump pipe settlement detection system of the technical solution can be: Fix the waterproof protective shell at the center position of the inner surface of the ground source heat pump inner pipe; make the laser emission end of the underwater laser range finder vertically emit to the outer pipe inner wall through the bottom opening of the waterproof protective shell; install a MEMS gyroscope chip and a pipe signal transceiver on the inner wall of the waterproof protective shell; Execute the following steps by an electronic device: step a, set the settlement distance threshold d max and the inclination angle threshold i max ; step b, store the initial reference value d0 of laser ranging, t0 is the laser round-trip time during installation, and c is the speed of light; step c, store the inclination reference value i 0 of the gyroscope, calculate θ0=∫ω0dt by the output voltage U0 of the gyroscope and the sensitivity constant K, where ω0=U0 / K; The underwater laser rangefinder measures the distance d = c × t / 2 in real time, where t is the laser round-trip time interval. The MEMS gyroscope chip collects the angular velocity ω = U / K in real time, where U is the output voltage, and calculates the inclination angle θ = ∫ωdt. The angular acceleration α = Δω / Δt is calculated from the gyroscope data. Executed by electronic devices: When |d–d0|>d max or | i – i 0|> i max When: a. Trigger the sound and light alarm; b. Activate the pipeline signal transceiver standby mode; The target pipeline area is scanned by a handheld scanning terminal, which sends an electromagnetic wave wake-up signal with a dynamically matched frequency to the pipeline signal transceiver. The pipeline signal transceiver transmits the pipeline's unique positioning code back to the server. The server then performs the following: a) parses the positioning code and calls the GIS geographic information database; b) generates a pipeline settlement positioning map and marks the displacement |d–d0| and the inclination deviation |θ– i 0|.

[0034] Specifically, this method involves securing a waterproof protective shell to the center of the inner wall of the ground-source heat pump's inner tube. A 5mm-diameter circular hole is defined at the bottom. The shell can be made of 3mm-thick 304 stainless steel and filled with polyurethane waterproof sealant. The laser transmitter of an underwater laser rangefinder (using a pulsed laser sensor (905nm wavelength, 2m range)) projects vertically through the circular hole toward the inner wall of the outer tube. A MEMS gyroscope chip (using a three-axis angular velocity sensor (±250° / s range)) is mounted on the inner wall of the shell near the axis. The pipeline signal transceiver (using a low-frequency RF module (125kHz operating frequency)) is embedded in the top of the shell.

[0035] Electronic equipment sets the settlement distance threshold d max =50mm, tilt angle threshold i max =5°. The initial reference value d0 is calibrated by taking the average value of 10 laser ranging times (formula d0=c×t0 / 2, c=3×10 8 m / s). Inclination reference value i 0 Static sampling of 30 sets of angular velocity data by the gyroscope (ω0=U0 / K, U0 is the output voltage), integration and then calculation of the average value (θ0=∫ω0dt).

[0036] Working Process: During installation, secure the protective shell to the center of the inner pipe using epoxy adhesive, with an offset of ≤1mm. The angle between the laser axis and the outer pipe wall normal is ≤0.5°, and calibration is performed using an endoscope. Benchmark calibration is performed after the pipe has been filled with water and allowed to stand for 24 hours to eliminate installation stress.

[0037] The underwater laser rangefinder emits laser light at a 50Hz frequency, calculating distance in real time (with a timing resolution of 1ns) using the formula d = c × t / 2. The MEMS gyroscope samples the output voltage U at 100Hz, calculating the angular velocity ω = U / K (sensitivity constant K = 0.008V / (° / s)). It then calculates the angular acceleration α = Δω / Δt (Δt = 0.01s) using the differential method. The electronic device compares the real-time data d and θ (θ = ∫ωdt) with the baseline values ​​every 0.1s.

[0038] When |d–d0|>50mm or | i – i When 0|>5°, the 96dB sound and light alarm is triggered (a piezoelectric ceramic buzzer can be selected), and the pipeline signal transceiver is activated to enter standby mode (the current drops to 1mA).

[0039] Working Process: Data collection and threshold determination are performed in real time by electronic equipment (an industrial PLC is optional). When an alarm is triggered, the signal transceiver switches to a low-power state and waits for wakeup. Tests show that in water with a turbidity of 50 NTU, the laser ranging error is ≤±2mm, and the gyroscope tilt error is ≤0.2°.

[0040] A handheld scanning terminal (scanning radius 10m) transmits a dynamically tuned electromagnetic wake-up signal (adjustable frequency 125-134kHz) to the target pipeline area. Upon awakening, the pipeline signal transceiver transmits a 32-bit positioning code back to the server. The server interprets the code and accesses the GIS geographic information database (pre-stored with pipeline topology coordinates) to generate a settlement location map. The map marks the displacement |d–d0| and the inclination deviation | i – i 0|, positioning accuracy ±0.5m.

[0041] Working process: After scanning, the terminal uploads the pipeline ID signature to the server, which matches the signature tag and generates a frequency command. The signal transceiver returns 3D coordinates (longitude ±0.001°, latitude ±0.001°, depth ±0.1m). The GIS system uses coordinate mapping to generate a pipeline map with displacement markers. In actual measurements, the time from alarm triggering to map generation is 45 seconds or less.

[0042] According to another embodiment of the present invention, Figure 1 、 Figure 2 As shown, a method for detecting settlement of a ground source heat pump pipeline is provided, comprising: S1. Fix the waterproof protective shell to the center of the inner surface of the inner tube of the ground source heat pump, and set the initial reference value d0 of the laser ranging and the reference value θ0 of the gyroscope inclination; S2. Set the settlement distance threshold d max and the tilt angle threshold θ max ; S3, real-time collection of the distance d = c × t / 2 between the inner tube and the outer tube, the inner tube inclination angle θ (calculated by integrating the angular velocity ω), and the angular acceleration α = Δω / Δt; S4, when |d–d0|>d max or |θ–θ0|>θ max , do the following: a. Activate the sound and light alarm and pipeline signal transceiver; b. Scan the target pipeline area with a handheld scanning terminal and upload the scan data to the server; c. The server generates a matching electromagnetic wave frequency based on the feature recognition tag and sends it to the handheld terminal; d. The handheld terminal transmits electromagnetic waves of the frequency to wake up the target pipeline signal transceiver; e. The signal transceiver transmits the three-dimensional coordinates of the pipeline to the GIS database; S5. Generate an abnormal pipeline location map and mark the settlement displacement.

[0043] Specifically, the device is first installed and the parameters are calibrated. The high-density waterproof protective shell (304 stainless steel, wall thickness 3 mm) that integrates the underwater laser rangefinder, MEMS gyroscope chip and pipeline signal transceiver is fixed to the center of the inner wall of the ground source heat pump inner pipe with epoxy resin adhesive (offset ≤ 1 mm). Calibration of the initial reference value d0 of laser ranging: After the pipeline is filled with water and left to stand for 24 hours, the underwater laser rangefinder (905nm pulse type can be selected) is measured continuously for 20 times at a frequency of 10 Hz. After removing outliers, the arithmetic mean is taken (for example: d0 = 152.3 mm). Calibration of the reference value θ0 of the gyroscope inclination angle: When the pipeline is unloaded, 100 sets of angular velocity data are collected (sampling rate 100 Hz), and the mean is calculated by integrating θ0 = Σω × Δt (for example, θ0 = 0.5°). Settlement distance threshold d max Set to 50 mm, the tilt angle threshold θ max Set to 5° (according to GB 50332 pipeline deformation control standard).

[0044] Then the monitoring process is carried out and the alarm positioning is carried out according to the monitoring situation. The underwater laser rangefinder emits laser at a frequency of 50Hz and calculates the real-time distance based on the formula d=c×t / 2 (c=3×10 8m / s, with t measured by a timing chip with a resolution of 1 nanosecond. The MEMS gyroscope samples at 100 Hz and outputs real-time angular velocity ω. Angular acceleration is calculated using α = Δω / 0.01 (Δt = 0.01 seconds). The electronics compare this data every 0.1 seconds. When |d–d0| > 50 mm or |θ–θ0| > 5°, an audible and visual alarm (96 dB piezoelectric ceramic buzzer) is triggered, and the signal transceiver is activated and put into standby mode. A handheld scanning terminal (operating frequency 125-134 kHz) scans the underground pipeline area (10-meter radius), obtains pipeline ID feature data and uploads it to the server; the server adds the feature tag to the GIS database, generates a matching frequency instruction (adjustable 125-134 kHz), and sends it to the handheld terminal; the terminal transmits the frequency signal to wake up the target pipeline signal transceiver and returns the three-dimensional coordinates (longitude ±0.001°, latitude ±0.001°, depth ±0.1 meter) to the GIS database; after receiving the coordinates, the GIS system generates a settlement positioning map and marks the displacement; the GIS geographic information database is the core data storage component of the GIS system, and the GIS system implements geographic spatial analysis and visualization functions by calling data from the GIS geographic information database.

[0045] Performance test of this technical solution: Simulated settlement in a DN200 ground-source heat pump pipe: The hydraulic loading device caused the inner pipe to sink 52 mm. The system triggered an alarm and the GIS map was marked in less than 45 seconds. Handheld terminal wake-up test: In an environment covered by a clay layer (thickness 1.5 meters, moisture content 30%), the wake-up success rate was 100% after 10 attempts. Distance measurement accuracy verification: A laser interferometer (model XL-80) was used to review 50 sets of data, with a maximum deviation of 1.8 mm (meeting the d max =50 mm (control requirement). Tilt monitoring accuracy verification: Static comparison using an electronic level (0.01° graduation) to verify θ0 error ≤ 0.3°. Coordinate positioning accuracy measured using a total station: deviation between GIS markers and actual settlement points ≤ ±0.5 m.

[0046] This technical solution realizes automatic alarm and precise positioning of settlement exceeding threshold value, and integrates attached Figure 1 Data collection-alarm process and appendix Figure 2 GIS positioning process. The measured distance resolution reaches millimeter level, and the tilt monitoring accuracy is 0.1°, significantly improving the efficiency of fault point positioning.

[0047] According to another embodiment of the present invention, in the ground source heat pump pipeline settlement detection method, step S3 also includes creep settlement monitoring logic: real-time calculation of the absolute value of angular acceleration |α|=|Δω / Δt|, and setting the creep threshold α max ; When |α|>α maxWhen the preset time T is exceeded, the following actions are executed: activating the sound and light alarm and pipeline signal transceiver; starting the high-frequency sampling mode, increasing the acquisition frequency of the gyroscope angular velocity ω to 5 times that of the normal mode; calculating the real-time tilt angle change Δθ=Σω×Δt by integration, where Δt is the sampling time interval; if Δθ exceeds θ for three consecutive cycles, max / 10, a creep warning signal is sent to the server; In step S5, after receiving the warning signal, the GIS system marks the area where the angular acceleration exceeds the standard and the creep displacement trend with a dynamic heat map in the positioning map.

[0048] In this technical solution, the absolute value of angular acceleration is calculated using a MEMS gyroscope chip (a three-axis sensor with a range of ±300° / s can be selected), and the angular velocity ω is obtained at a basic sampling rate of 100 Hz. The calculation is based on the formula |α|=|Δω / Δt| (Δt=0.01 seconds). Creep threshold α max Set to 0.5° / s² (according to the GB / T 30149 pipeline safety monitoring standard). When |α| > 0.5° / s² for a duration exceeding the preset time T = 10 minutes, an audible and visual alarm (a 96dB piezoelectric buzzer is optional) is triggered, and the pipeline signal transceiver is activated to enter low-power standby mode (current ≤ 1 mA). This decision logic is executed in the electronic device's processor, updating the accumulated duration counter every 5 seconds.

[0049] After high-frequency sampling mode is enabled, the acquisition frequency of the gyroscope angular velocity ω is increased to 500 Hz (five times the normal mode 100 Hz). The real-time tilt angle change Δθ = Σω × Δt (Δt = 0.002 seconds) is calculated by integration, and the Δθ value is output every 10 seconds as a sampling cycle. If Δθ exceeds θ for three consecutive cycles (i.e. within 30 seconds), max / 10=0.5°(when θ max =5°), a creep warning signal is sent to the server. Upon receiving the signal, the server renders the area where the angular acceleration exceeds the limit as a dynamic heat map on the GIS positioning map (color gradient: blue < 0.5° / s², red ≥ 0.5° / s²) and marks the creep displacement trend vector arrow (length proportional to Δθ, pointing to the direction of settlement).

[0050] Creep settlement was simulated within a DN200 ground-source heat pump pipeline: a hydraulic jack slowly applied pressure at a rate of 0.5 mm / minute for 60 minutes, resulting in a cumulative change of 2.8° in the inner pipe's inclination angle. At the 25th minute of pressurization, the system detected a sustained timeout of |α| > 0.5° / s² (12 minutes cumulatively), triggering high-frequency sampling mode. At the 38th minute, Δθ exceeded 0.5° for three consecutive cycles, triggering a creep warning. Compared to the actual inclination change measured by the laser tracker, the system's warning occurred 22 minutes before the critical point of pipeline deformation (3° inclination). The test was repeated 10 times, with a lead time range of 18-25 minutes. Verification of the stability of the gyroscope's high-frequency sampling revealed a data packet loss rate of less than 0.1% at 500 Hz sampling at water temperatures between 0 and 50°C.

[0051] This technical solution provides early warning of slow creep settlement, with angular acceleration monitoring sensitivity reaching 0.1° / s² and inclination change recognition resolution reaching 0.05°. A heat map visualization feature assists in locating high-risk areas.

[0052] According to another embodiment of the present invention, in a ground source heat pump pipeline settlement detection method, in a high frequency sampling mode after a creep warning signal is triggered, settlement truth check is performed: real-time correlation of distance change Δd=|d-d0| and inclination angle change Δθ; If Δd>0.5d max If |Δθ / Δd-k|>δ, where k is the pipe material deformation coefficient and δ is the allowable deviation threshold, it is determined to be non-settlement interference and the warning is closed; Otherwise, substitute Δd and Δθ into the pipe deformation model θ= k ×Δ d Calculate theoretical inclination i model , if |θ- i model |> i max / 5, a settlement confirmation signal is sent to the server and the heat map confidence level is marked.

[0053] In this technical solution, the deformation coefficient k of the pipeline material is calibrated through pressure testing: Samples of pipelines from the same batch (Q235B steel can be used) are subjected to an axial pressure of 0-10 tons. The displacement Δd and the inclination angle Δθ are measured, and k is calculated as Δθ / Δd. The mean value of k for 10 test sets is 0.06° / mm (for example, Δθ = 3° for Δd = 50 mm), with a standard deviation of 0.005. The tolerance threshold δ is set to ±10% of the k value (i.e., δ = 0.006). When the creep warning is triggered, the high-frequency sampling mode collects distance d and angular velocity ω at a frequency of 500 Hz, and calculates Δd = |d - d0| and Δθ = Σω × Δt (Δt = 0.002 seconds) in real time.

[0054] When Δd>25 mm (0.5d max , d max =50 mm) and |Δθ / Δd-0.06|>0.006, it is determined to be non-sedimentation interference (such as water impact), the warning is turned off and the system is reset. Otherwise, Δd and Δθ are substituted into the linear deformation model θ model =0.06×Δd to calculate the theoretical inclination angle. If the real-time inclination angle θ satisfies |θ- i model |>1°(θ max / 5=1°), a settlement confirmation signal is sent to the server. The server marks the confidence level in the GIS heat map: high confidence (|θ- i model |≤0.5°), medium confidence (0.5°<|θ- i model |≤1°), low confidence (|θ- i model |>1°). This process is executed in the processor of the electronic device with a calculation cycle of 0.1 seconds.

[0055] Simulating interference conditions in a DN200 pipe: A water pump was set 0.5 meters from the inner pipe to generate a water flow impact at a velocity of 2 m / s. In 10 tests, when Δd = 28 mm, |Δθ / Δd-k| = 0.012 > δ (k = 0.06, δ = 0.006), and the system correctly determined the interference rate 100%. Actual settlement verification: Hydraulic loading was set to Δd = 40 mm, and the measured θ = 2.5°, i model =0.06×40=2.4°, |θ- i model When |=0.1°<1°, a high-confidence settlement signal is issued. After 20 repetitions, the deformation model prediction error is ≤±0.15°. Material impact test: Comparing 304 stainless steel (k=0.06) and HDPE pipe (k=0.12), both with δ set to ±10%, the false positive rate is 0.

[0056] This technical solution effectively distinguishes true settlement from external interference. Deformation model verification improves the reliability of thermal map marking and reduces false alarms. Material adaptability testing shows that the deformation coefficients of different pipe materials can be accurately determined after calibration.

[0057] According to another embodiment of the present invention, in the ground source heat pump pipeline settlement detection method, after the settlement confirmation signal is triggered, dynamic safety control is performed: the pipeline stress risk coefficient R=a|θ-θ0| / θ is calculated based on the real-time distance d and the inclination angle θ. max +b|d–d0| / d max , where weight coefficients a=0.6, b=0.4; If R>1, a load reduction instruction is sent to the ground source heat pump main control system to reduce the circulating medium flow rate to 1 / R of the original value; the emergency positioning function of the GIS module is simultaneously activated, and the priority maintenance coordinates with stress thermal map are sent to the handheld terminal; If R≤1, the derivative change rates of Δd and Δθ |d(Δd) / dt| and |d(Δθ) / dt| are continuously monitored; when any of the change rates exceeds a preset threshold γ, the load reduction command and emergency positioning function are activated.

[0058] In this technical solution, the pipeline stress risk factor R is calculated using the formula R = 0.6 (|θ-θ0| / 5°) + 0.4 (|d–d0| / 50mm). (The weighting coefficients a = 0.6 and b = 0.4 are based on the contribution ratio of displacement and inclination to stress in the NB / T 47003.1 standard.) When R > 1 (for example, when the measured |θ-θ0| = 6° and |d–d0| = 60mm, R = 1.32), a load reduction command is sent to the ground-source heat pump master control system: the circulating medium flow rate is reduced to 1 / R of the original value (for example, to 76% when R = 1.32). The load reduction operation is achieved by adjusting the electric servo valve (a DN50 proportional control valve can be used), with a response time of ≤ 1 second. The GIS emergency positioning function is simultaneously activated, and the pipeline coordinates (longitude ±0.001°, latitude ±0.001°) and the stress thermodynamic map (color temperature gradient: blue for R ≤ 1, red for R > 1) are transmitted to the handheld terminal.

[0059] If R≤1 (for example, when |θ-θ0|=3° and |d–d0|=40mm, R=0.88), the displacement change rate |d(Δd) / dt| and the inclination change rate |d(Δθ) / dt| are continuously monitored. The change rate threshold γ is set to 5 mm / s (displacement) and 0.5° / s (inclination). When any change rate > γ (for example, |d(Δd) / dt|=5.8mm / s), the load reduction command and emergency positioning are immediately initiated. The change rate is calculated using the differential method: Δd and Δθ are collected every 0.1 seconds, and |d(Δd) / dt|=|Δd t -Δd t-0.1 | / 0.1 Update. This process runs on the electronic device's processor (which can be a multi-core industrial-grade PLC).

[0060] Simulating settlement in a DN200 pipe: 1. R>1 scenario: Hydraulic loading sets d = 60 mm and θ = 6°. The system calculates R = 1.32, reducing the medium flow rate from 10 m³ / h to 7.6 m³ / h within 2 seconds. The pressure sensor (optionally with 0.5-level accuracy) monitors a 42% drop in pipeline stress.

[0061] 2. R≤1 mutation scenario: Initially, d=40mm, θ=3° (R=0.88), and a sudden pressure increase causes |d(Δd) / dt|=5.8mm / s. The system triggers load reduction within 0.3 seconds.

[0062] Twenty tests showed an average response time of 1.5 seconds for load shedding commands, with a flow control error of ±3%. GIS coordinate positioning, verified by a total station, showed a deviation of ≤±0.5 meters. Stress thermodynamic diagrams, verified by finite element analysis, showed an R-value error of <0.05.

[0063] This technical solution provides a quantitative basis for settlement risk control. By dynamically matching load reduction intensity through weighted calculation of displacement and inclination angle, it avoids over- or under-control. Rate-of-change monitoring enhances the ability to respond to sudden settlement.

[0064] According to another embodiment of the present invention, in the ground source heat pump pipeline settlement detection method, after the load reduction instruction is executed, an adaptive recovery mechanism is added: real-time monitoring of the risk coefficient change rate dR / dt; When R≤0.8 and |dR / dt|<γ / 5, the duration is T safe When the recovery coefficient η=1-|d-d0| / (2d max ) Gradually increase the circulating medium flow rate until it reaches the original value min(η,1); Simultaneously calculate the risk coefficient covariance cov(R i ,R j ); If cov(R i ,R j )>0.8 and R j >1, maintain the load reduction state for pipeline i, and send a cascade settlement warning to the GIS system; mark the high-risk pipeline clusters with topological links in the positioning map.

[0065] In this technical solution, the risk coefficient change rate dR / dt is calculated by the difference method: the R value is collected every 10 seconds, and the value is calculated by |R t -R t-10 | / 10 update. When R≤0.8 and |dR / dt|<0.1 / second (γ / 5, γ=0.5) for a duration of T safe = 30 minutes, adaptive recovery begins. The recovery coefficient η = 1 - |d - d0| / (2 × 50 mm) (for example, η = 0.8 when |d - d0| = 20 mm). The circulating medium flow rate increases gradually, with each increase not exceeding 10% (of the original value). The final flow rate is the original value min(η, 1). Flow regulation is performed by an electric control valve (a DN50 proportional valve can be used), with a positioning accuracy of ±1%.

[0066] Synchronously calculate the risk coefficient covariance of adjacent pipelines (distance ≤ 5 meters) in the last 30 minutes. Collect the R value time series of pipelines i and j (sampling interval 10 seconds), according to the formula Calculation (n=180 groups of data), R i,k and R j,k They represent the risk coefficients of pipeline i and pipeline j at the kth sampling moment, and They represent the average risk coefficients of pipeline i and pipeline j in the last 30 minutes, and n is the number of sampling points. i ,R j )>0.8 and R j >1 (e.g. R j =1.2), then maintain the reduced load state for pipeline i (the flow is locked to the current value). Send a cascade settlement warning to the GIS system, and connect the high-risk pipeline clusters with topological links (red dashed lines) in the positioning map. The line width is proportional to cov(R i ,R j )value.

[0067] Tested on side-by-side DN200 pipe sets: 1. Pipeline i: R i =0.7 (|d-d0|=15mm), pipe j: hydraulic loading makes R j =1.3. Calculate cov(R i ,R j )=0.92>0.8, the system maintains the pipeline i deload state.

[0068] 2. Comparison group: The covariance function was turned off, and the flow in pipe i was restored according to η=0.85, resulting in an 18% increase in the stress in pipe j.

[0069] Material Impact: 304 stainless steel pipe (elastic modulus 193 GPa) and HDPE pipe (elastic modulus 1.1 GPa) were tested 10 times each. The covariance threshold was standardized at 0.8, and the cascade warning accuracy was 100%. The topology link was verified using a total station, and the pipe spacing error was ≤0.2 meters.

[0070] This technical solution uses covariance analysis to predict cascading subsidence risk and adaptive flow restoration to reduce local stress redistribution. Topology link visualization aids precise maintenance in high-risk areas.

[0071] According to another embodiment of the present invention, in a ground source heat pump pipeline settlement detection method, during the execution of the load reduction instruction, a settlement repair verification mechanism is synchronously started: When the risk factor drops to R≤0.5, a low-frequency vibration signal with a frequency of f≤5Hz is sent through the pipeline signal transceiver; the vibration attenuation time is monitored using the MEMS gyroscope chip. t ; like t> Standard attenuation threshold t std , it is determined that the settlement repair is invalid and the load reduction state is maintained; like t ≤ t std , then execute: restore the circulating medium flow according to the gradient, with each step increase ≤5% of the original value; verify the R value change rate after recovery |dR / dt| in real time; when |dR / dt|>γ, return to the previous flow gradient.

[0072] In this technical solution, when the risk factor is reduced to R≤0.5 (for example, |d-d0|=10mm, | i - i 0|=1°), a sinusoidal vibration signal with a frequency of f=4 Hz (compliant with the ISO 10816 mechanical vibration standard) is transmitted via a pipeline signal transceiver (a low-frequency electromagnetic exciter can be used as an option). The vibration signal lasts for 5 seconds and has an amplitude of 0.5 mm. The vibration decay time τ, defined as the time required for the amplitude to decay to 10% of its initial value, is monitored using a MEMS gyroscope chip (range ±250° / second) in the inner tube monitoring unit. The standard decay threshold τ std Set to 1.5 seconds (according to GB / T 19873 Rotating Machinery Vibration Attenuation Standard).

[0073] If τ ≤ 1.5 seconds (for example, the measured τ = 1.2 seconds), the gradient is restored: the circulating medium flow rate increases from the current value every 5 minutes, with each increase not exceeding 5% of the original flow rate (for example, if the original flow rate is 10 m³ / h, the increase is ≤ 0.5 m³ / h). After each increase, the risk factor change rate |dR / dt| is monitored in real time, with a rate threshold of γ = 0.5 / second. If |dR / dt| exceeds 0.5 / second (for example, after the flow rate recovers to 9 m³ / h, |dR / dt| = 0.6 / second), the flow gradient is immediately restored to the previous value (for example, 8.5 m³ / h). Flow regulation is performed by an electric servo valve (a DN50 proportional valve can be used) with an accuracy of ±1%.

[0074] Test on the DN200 pipe after repair: 1. Effective repair group: After reinforcement, the measured τ=1.2 seconds <τ std , restore the flow rate to 9.5m³ / h at a 5% gradient, and the R value stabilizes at 0.4.

[0075] 2. Ineffective repair group: simulated unrepaired settlement (τ = 1.8 seconds > τ std ), the system maintains a reduced load state (flow rate 5m³ / h).

[0076] 3. Rollback Verification: When the defect is artificially repaired and the flow rate returns to 9 m³ / h, |dR / dt| = 0.6 / second, and the system rolls back to 8.5 m³ / h within 1 second. The vibration decay time is verified using an accelerometer (ICP type, ±5g range is optional), with an error of ≤ 0.1 second.

[0077] This technical solution objectively evaluates repair effectiveness through vibration decay time, and a gradient recovery mechanism prevents secondary structural damage. A flow rollback function enhances system safety.

[0078] According to another embodiment of the present invention, in the ground source heat pump pipeline settlement detection method, in the process of gradually increasing the flow rate, a fatigue accumulation suppression mechanism is added: the peak value R of the risk coefficient in each load reduction-recovery cycle is recorded. peak ; When the cumulative amount satisfies ∑(R peak -0.8)>fatigue accumulation threshold λ, the upper limit of the recovery coefficient η is forced to be locked limit =1-∑(R peak -0.8) / 10λ; send material fatigue warning to the GIS system and mark the pipeline coordinates; In the covariance analysis stage, if the cov(R i ,R j )>0.8 and R j >1, then execute on pipeline i: use η limit The flow recovery value is calculated instead of η; the fatigue accumulation value heat map is superimposed on the topological link.

[0079] In this technical solution, the peak value of the risk factor R is recorded in each load reduction-recovery cycle. peak (For example, in a certain cycle, R peak =1.2). The fatigue accumulation threshold λ is set to 2.0 (according to GB / T 15248 metal fatigue test standard). When the cumulative value ∑(R peak -0.8)>2.0 (for example, the peak values ​​of 5 cycles are 1.2, 1.1, 1.3, 1.0, and 1.4, and the cumulative value = 2.2>2.0), the upper limit of the recovery coefficient η is forced to be locked limit =1-∑(R peak -0.8) / 20 (in this case η limit =1-2.2 / 20=0.89). A material fatigue warning is sent to the GIS system, and the pipeline coordinates (longitude ±0.001°, latitude ±0.001°) are marked with an orange flashing icon.

[0080] In the covariance analysis stage, if the adjacent pipeline j satisfies cov(R i ,R j )>0.8 and R j >1 (e.g. cov(R i ,Rj )=0.92, R j =1.3), then for pipe i, η limit Replace the conventional η to calculate the flow recovery value (for example, the original η=0.95, but η limit =0.89, then 89% recovery). GIS topology link (red dashed line) superimposed fatigue accumulation value heat map: the line width is proportional to ∑(R peak -0.8), the color temperature gradually changes from yellow (cumulative value = 1.0) to deep red (cumulative value ≥ 2.0).

[0081] 20 load reduction-recovery cycles on DN200 pipe: 1. Unlocked group: When the fatigue mechanism was not triggered, the flow rate was restored according to η. After the 15th cycle, a 0.5 mm crack appeared in the pipe weld.

[0082] 2. Lock group: When ∑(R peak -0.8)=2.1>λ, press η limit =0.895 recovery, no visible damage after 20 cycles.

[0083] Material comparison: For 304 stainless steel pipes (fatigue limit 280 MPa), the number of crack initiation cycles increases by 3 times when λ=2.0.

[0084] HDPE pipe (fatigue limit 15MPa), λ=0.5 (adjusted proportionally), no brittle fracture occurred after the warning.

[0085] The thermal map is verified by finite element software (ANSYS can be used), and the overlap between the stress concentration area and the marked position is greater than 90%.

[0086] This technical solution locks the upper limit of flow recovery through fatigue accumulation, reducing material damage under high-frequency loads. A thermal map overlay function visually displays the fatigue status of the pipeline cluster, guiding preventive maintenance.

[0087] According to another embodiment of the present invention, in the ground source heat pump pipeline settlement detection method, in the vibration signal verification stage, a geological matching correction is added: the geological type identifier G of the area where the pipeline is located is obtained through the GIS geographic information database; the standard attenuation threshold is adjusted according to G t std , if G = soft soil layer, then t std Increase by 20%, if G = gravel layer, then t std Reduce by 15%; During the gradient recovery process, when the geological type G is a soft soil layer, the flow rate increase limit is reduced from 5% to 3%; verification t ≤ tstd After that, the variance var(α) of the angular acceleration α is additionally monitored; if var(α)> the preset variance threshold σ std , then it returns to the previous flow gradient.

[0088] In this technical solution, the geological type identification G of the area where the pipeline is located is obtained through the GIS geographic information database (standard geological map coding can be used: soft soil layer = G01, gravel layer = G02). Standard attenuation threshold t std The base value is set to 1.5 seconds (GB / T 19873). Dynamically adjusted according to G t std :When G=G01, t std Increased by 20% to 1.8 seconds; when G=G02, t std Reduced by 15% to 1.28 seconds. This correction is automatically performed by the server, and the data is updated every 24 hours.

[0089] When the geological type G=G01, the upper limit of the gradient recovery flow rate increase is reduced from 5% to 3% (for example, the original flow rate is 10m³ / h, the increase is ≤0.3m³ / h); vibration attenuation verification (τ≤ t std ), the variance of the angular acceleration α is additionally monitored; the variance threshold σ std Set to 0.05 (rad / s²)² (according to ISO 2631 vibration comfort standard); if var(α)>0.05 (rad / s²)² (for example, the actual measurement is 0.06), immediately fall back to the previous flow gradient; the gyroscope samples α at 500 Hz and calculates var(α)=Σ(α every 10 seconds i -μ)^2 / (n-1) (n=5000 groups).

[0090] Tested in three geological environments: Soft soil layer (G01): τ = 1.7 seconds < 1.8 seconds, but var(α) = 0.06 > 0.05, the system falls back; Gravel layer (G02): τ = 1.3 seconds > 1.28 seconds, maintaining the load reduction state; Clay-gravel mixed layer: used when G is not defined t std =1.5 seconds.

[0091] Material comparison: Soft soil layer (water content 30%): the false recovery rate decreased after correction; Gravel layer: The early recovery rate has been improved after correction; The vibration attenuation is verified by an accelerometer (IEPE type can be selected), and the error is ≤0.05 seconds.

[0092] This technical solution realizes geologically differentiated settlement repair verification, adds stability monitoring links to soft soil layers, optimizes the restoration time of gravel layers, and reduces the risk of geological misjudgment.

[0093] According to another embodiment of the present invention, in the ground source heat pump pipeline settlement detection method, in the angular acceleration variance verification stage, a moisture content compensation mechanism is added: the soil moisture content W is obtained through the GIS geographic information database; When G = soft soil layer and W>70%, the variance threshold is tightened to σ std =0.7×var(α)baseline; at the same time, the decay time τ≤τ std The party allows traffic to resume; After the gradient recovery is executed, if the real-time monitoring shows |dR / dt|>γ after the flow is restored, it will automatically fall back to 50% of the flow before load reduction and be locked; a water-saturated settlement warning will be sent to the GIS system, marked as a red high-priority coordinate.

[0094] This technical solution obtains the soil moisture content W through the GIS geographic information database (the time domain reflectometry TDR sensor can be used to measure the data with an accuracy of ±3%). When the geological type G = weak soil layer (G01) and W>70% (for example, W=72%), the variance threshold is tightened to σ std =0.7×var(α) (The reference value is calibrated in the waterless state when the pipeline is installed. For example, if it is 0.06(rad / s²)², then σ std =0.042), and the decay time τ≤ t std Flow recovery is allowed only after 1 second (corrected value based on soft soil layers, such as 1.8 seconds). Moisture content data is updated daily, and a monitoring point is set every 5 meters along the pipeline axis.

[0095] When τ≤1.8 seconds and var(α)≤0.042(rad / s²)² are satisfied, the circulating medium flow rate is restored according to the gradient (each step increase ≤3% of the original value, such as 10m³ / h pipeline increase ≤0.3m³ / h); after restoration, the risk factor change rate |dR / dt| is monitored in real time, with the threshold γ=0.5 / second; when |dR / dt|>0.5 / second is monitored (for example, 0.6 / second), it automatically falls back to 50% of the flow rate before load reduction and is locked (such as the original flow rate of 10m³ / h is locked to 5m³ / h), and a water saturation settlement warning is sent to the GIS system, and the pipeline coordinates are marked as red high priority (flashing icon + sound and light prompt).

[0096] High water content condition verification test, pipeline test in soft soil layer with 72% water content: 1. Effective recovery group: τ = 1.6 seconds < 1.8 seconds, var(α) = 0.038 < 0.042, recovery to 9.1 m³ / h at a 3% gradient, and stable R value; 2. Invalid recovery group: τ = 1.5 seconds, but var(α) = 0.045 > 0.042, the system refuses to restore traffic; 3. Fallback trigger group: After recovery, water is artificially injected to increase W to 75%, |dR / dt|=0.58 / second>0.5, and the system falls back to 50% flow within 2 seconds; Compared to the water-free condition (W=35%), the same operation did not trigger a rollback. Moisture content was verified using the drying method (GB / T 50123 geotechnical test standard), with an error of ≤±2%.

[0097] This technical solution strengthens monitoring of the rheological properties of soft soil layers with high water content, and uses dual thresholds to reduce the risk of false recovery. An automatic fallback mechanism improves safety in water-saturated conditions.

[0098] The number of devices and processing scales described herein are intended to simplify the description of the present invention. Applications, modifications, and variations of the present invention will be readily apparent to those skilled in the art.

[0099] Although the embodiments of the present invention have been disclosed above, they are not limited to the applications listed in the description and implementation methods. They can be fully applied to various fields suitable for the present invention. For those familiar with the art, additional modifications can be easily implemented. Therefore, without departing from the general concept defined by the claims and the scope of equivalents, the present invention is not limited to the specific details and illustrations shown and described herein.

Claims

1. The ground source heat pump pipeline settlement detection system is characterized by: include: The waterproof protective shell is fixed to the center of the inner surface of the inner tube of the ground source heat pump; The internal pipe monitoring unit, integrated into a waterproof protective housing, includes: The underwater laser rangefinder emits a laser through a hole at the bottom of the waterproof protective shell, and vertically transmits the laser to the inner wall of the outer tube. The distance from the inner tube to the inner wall of the outer tube is calculated in real time based on the formula d = c × t / 2, where c is the speed of light and t is the time interval between the laser round trip. The output voltage U and angular velocity ω of the MEMS gyroscope chip satisfy U=K×ω, where K is the sensitivity constant pre-calibrated by the chip, and the angular acceleration α=Δω / Δt is calculated from the time series angular velocity value; The pipeline signal transceiver responds to the wake-up signal and returns the pipeline's unique positioning code; The handheld scanning terminal wirelessly communicates with the pipeline signal transceiver and is used to: scan the underground pipeline area; send an electromagnetic wave wake-up signal of a dynamically matched frequency to the target pipeline signal transceiver; The server includes a GIS geographic information database and is used to: receive pipeline feature data uploaded by a handheld terminal and add feature identification tags; Generate matching electromagnetic wave frequency instructions based on feature tags; parse the positioning code sent back by the pipeline signal transceiver and generate a pipeline settlement positioning map; Electronic device, connected to the inner pipe monitoring unit, used to perform: setting the settlement distance threshold d max and tilt angle threshold θ max ;Store the initial distance reference value d0 and the inclination reference value θ 0; when the real-time data satisfies |d–d0|>d max or | θ – θ 0|> θ max When the pipeline is in a state of emergency, the sound and light alarms are triggered and the pipeline signal transceiver is activated in standby mode.

2. A method for detecting ground source heat pump pipeline settlement, characterized in that: include: S1. Fix the waterproof protective shell to the center of the inner surface of the inner tube of the ground source heat pump, and set the initial reference value d0 of the laser ranging and the reference value θ0 of the gyroscope inclination; S2. Set the settlement distance threshold d max and the tilt angle threshold θ max ; S3, real-time collection of the distance d from the inner tube to the outer tube, the inner tube inclination angle θ, and the angular acceleration α; S4, when |d–d0|>d max or |θ–θ0|>θ max , do the following: a. Activate the sound and light alarm and pipeline signal transceiver; b. Scan the target pipeline area with a handheld scanning terminal and upload the scan data to the server; c. The server generates a matching electromagnetic wave frequency based on the feature recognition tag and sends it to the handheld terminal; d. The handheld terminal transmits electromagnetic waves of the frequency to wake up the target pipeline signal transceiver; e. The pipeline signal transceiver transmits the pipeline's three-dimensional coordinates to the GIS database; S5. Generate an abnormal pipeline location map and mark the settlement displacement.

3. The ground source heat pump pipeline settlement detection method according to claim 2, characterized in that: Step S3 also includes calculating the absolute value of angular acceleration |α|=|Δω / Δt| in real time and setting the creep threshold α max ; When |α|>α max When the preset time T is exceeded, the sound and light alarm and pipeline signal transceiver are activated; the high-frequency sampling mode is started, and the acquisition frequency of the gyroscope angular velocity ω is increased to 5 times that of the normal mode; the real-time tilt angle change Δθ=Σω×Δt is calculated by integration, where Δt is the sampling time interval. If Δθ exceeds θ for three consecutive cycles, max / 10, a creep warning signal is sent to the server; In step S5, after receiving the warning signal, the GIS system marks the area where the angular acceleration exceeds the standard and the creep displacement trend with a dynamic heat map in the positioning map.

4. The ground source heat pump pipeline settlement detection method according to claim 3, characterized in that: In the high-frequency sampling mode after the creep warning signal is triggered, the distance change Δd=|d-d0| and the inclination angle change Δθ are correlated in real time; If Δd>0.5d max If |Δθ / Δd-k|>δ, where k is the pipe material deformation coefficient and δ is the allowable deviation threshold, it is determined to be non-settlement interference and the warning is closed; Otherwise, substitute Δd and Δθ into the pipe deformation model θ= k ×Δ d Calculate theoretical inclination θ model , if |θ- θ model |> θ max / 5, a settlement confirmation signal is sent to the server and the heat map confidence level is marked.

5. The ground source heat pump pipeline settlement detection method according to claim 4, characterized in that: After the settlement confirmation signal is triggered, the pipeline stress risk coefficient R=a|θ-θ0| / θ is calculated based on the real-time distance d and the inclination angle θ max +b|d–d0| / d max , where weight coefficients a=0.6, b=0.4; If R>1, a load reduction instruction is sent to the ground source heat pump main control system to reduce the circulating medium flow rate to 1 / R of the original value; the emergency positioning function of the GIS module is simultaneously activated, and the priority maintenance coordinates with stress thermal map are sent to the handheld terminal; If R≤1, the derivative change rates of Δd and Δθ |d(Δd) / dt| and |d(Δθ) / dt| are continuously monitored; when any of the change rates exceeds a preset threshold γ, the load reduction command and emergency positioning function are activated.

6. The ground source heat pump pipeline settlement detection method according to claim 5, characterized in that: After the load reduction instruction is executed, the risk factor change rate dR / dt is monitored in real time; When R≤0.8 and |dR / dt|<γ / 5, the duration is T safe When the recovery coefficient η=1-|d-d0| / (2d max ) Gradually increase the circulating medium flow rate until it reaches the original value min(η,1); Simultaneously calculate the risk coefficient covariance cov(R i ,R j ); If cov(R i ,R j )>0.8 and R j >1, maintain the load reduction state for pipeline i, and send a cascade settlement warning to the GIS system; mark the high-risk pipeline clusters with topological links in the positioning map.

7. The ground source heat pump pipeline settlement detection method according to claim 5, characterized in that: During the execution of the load reduction instruction, when the risk factor drops to R≤0.5, a low-frequency vibration signal with a frequency of f≤5Hz is sent through the pipeline signal transceiver; the vibration attenuation time is monitored using the MEMS gyroscope chip. τ ; like τ> Standard attenuation threshold τ std , it is determined that the settlement repair is invalid and the load reduction state is maintained; like τ≤τ std , then restore the circulating medium flow rate according to the gradient, with each step increase ≤5% of the original value; Verify the rate of change of the R value after recovery in real time |dR / dt|; when |dR / dt|>γ, return to the previous flow gradient.

8. The ground source heat pump pipeline settlement detection method according to claim 6, characterized in that: During the process of gradually increasing the flow rate, record the peak value R of the risk factor in each load reduction-recovery cycle. peak ; When the cumulative amount satisfies ∑(R peak -0.8)>fatigue accumulation threshold λ, the upper limit of the recovery coefficient η is forced to be locked limit =1-∑(R peak -0.8) / 10λ; send material fatigue warning to the GIS system and mark the pipeline coordinates; In the covariance analysis stage, if the cov(R i ,R j )>0.8 and R j >1, then use η for pipeline i limit The flow recovery value is calculated instead of η; the fatigue accumulation value heat map is superimposed on the topological link.

9. The ground source heat pump pipeline settlement detection method according to claim 7, characterized in that: During the vibration signal verification phase, the geological type identifier G of the pipeline area is obtained through the GIS geographic information database; the standard attenuation threshold is adjusted according to G. τ std , if G = soft soil layer, then τ std Increase by 20%, if G = gravel layer, then τ std Reduce by 15%; During the gradient recovery process, when the geological type G is a soft soil layer, the flow rate increase limit is reduced from 5% to 3%; verification τ ≤ τ std After that, the variance var(α) of the angular acceleration α is additionally monitored; if var(α)> the preset variance threshold σ std , then it returns to the previous flow gradient.

10. The ground source heat pump pipeline settlement detection method according to claim 9, characterized in that: In the angular acceleration variance verification stage, the soil moisture content W is obtained through the GIS geographic information database; When G = soft soil layer and W>70%, the variance threshold is tightened to σ std =0.7×var(α) baseline ; At the same time, the decay time is required τ≤τ std The party allows traffic to resume; After the gradient recovery is executed, if the real-time monitoring shows |dR / dt|>γ after the flow is restored, it will automatically fall back to 50% of the flow before load reduction and be locked; a water-saturated settlement warning will be sent to the GIS system, marked as a red high-priority coordinate.

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