Ground source heat pump pipe settlement detection system and method

Abstract

The application discloses a kind of ground source heat pump pipeline settlement detection systems and methods, belong to underground energy facilities safety monitoring technical field, mainly solve the problem of low precision, difficult implementation of traditional detection means in underwater environment.It is fixed in the inner wall of ground source heat pump by waterproof protective shell, integrated underwater laser range finder is vertically emitted laser to the inner wall of outer tube, based on formula d=c×t / 2 Real-time calculation settlement distance;While using gyroscope chip to monitor inner tube inclination, output voltage U and angular velocity ω satisfy U=K×ω, and change of inclination is analyzed by angular acceleration α=Δω / Δt;Combining with GIS module to collect geospatial data, upload pipeline characteristics to server by handheld terminal, generate settlement positioning map;Electronic equipment sets threshold d max 、 θ max , when real-time data exceeds threshold, trigger audible light alarm.The application is used for high-precision monitoring of pipeline settlement displacement and inclination change, realizes fault automatic early warning and accurate positioning maintenance.

Description

Technical Field

[0001] This invention relates to the field of underground pipeline safety monitoring technology, specifically to a ground source heat pump pipeline settlement detection system and method. Background Technology

[0002] Ground source heat pump pipelines are buried in complex underground geological environments for extended periods, making them susceptible to uneven settlement due to soil pressure, groundwater level changes, and geological activity. This settlement alters the distance and tilt angle between the inner and outer pipes, potentially leading to misalignment, leakage, or even structural fracture, directly impacting the safe operation of the heat pump system. Traditional detection methods face three main challenges: First, the underwater environment limits detection accuracy. Ground source heat pump pipelines are often located in enclosed environments filled with groundwater or mud. Conventional mechanical contact measuring tools (such as telescopic rulers) are easily affected by water turbidity, buoyancy, and corrosion, making stable contact with the pipe wall difficult. Non-contact sonar detection suffers from underwater clutter interference, resulting in distorted echo signals and distance measurement errors often exceeding ±10 cm, failing to meet millimeter-level settlement monitoring requirements. Second, quantifying the relative displacement between the inner and outer pipes is challenging. Existing technologies primarily rely on sensors fixed to the outer pipe to indirectly estimate the inner pipe's condition. However, the presence of multiple layers of insulation and buffer structures between the inner and outer pipes absorbs some displacement due to deformation, leading to significant discrepancies between the actual inner pipe settlement value and the outer pipe monitoring data. Furthermore, uneven stress distribution in curved sections of the pipeline further amplifies measurement errors, and manual remeasurement is time-consuming and cannot cover the entire line. Thirdly, changes in tilt angle are difficult to capture in real time. Pipeline settlement is often accompanied by changes in tilt angle, and tilt angle monitoring relies on high-precision inertial devices. Conventional inclinometers, limited by size and waterproofing, cannot be implanted in the narrow space of the inner pipe; externally installed tilt sensors, due to their non-rigid connection to the inner pipe, can only reflect local attitude and cannot establish a full-pipe axis tilt model. Simultaneously, fluctuations in underwater ambient temperature cause zero-point drift in the sensors, requiring frequent calibration and making long-term continuous monitoring difficult.

[0003] The aforementioned problems arise primarily from uncontrollable geological conditions (such as creep in soft soil layers), the unique physical environment of underwater (medium refraction, turbulent disturbances), and limitations in sensor integration technology (size, pressure resistance, signal interference immunity). Previous attempts to improve the situation have included using fiber optic grating sensors, but their deployment requires damaging the pipeline insulation layer; or introducing underwater robots for inspection, but these are costly and cannot be embedded inside the pipeline. Therefore, there is an urgent need to develop a highly reliable settlement detection technology that can be implanted inside pipelines, adapt to the underwater environment, and simultaneously monitor distance and inclination. Summary of the Invention

[0004] This invention provides a ground source heat pump pipeline settlement detection system and method, aiming to solve the problems of real-time synchronous monitoring of the distance and inclination angle between the inner and outer pipes in underwater environments, the difficulty of implanting traditional sensors in the narrow space of the inner pipe, and poor data coordination leading to missed settlement faults. It addresses the issues of needing to manually scan and locate fault points when settlement exceeds a threshold, resulting in delayed response and excessively long confirmation times for hidden underwater environment coordinates. It also addresses the problem that conventional sampling frequencies cannot identify creep settlement caused by small, continuous changes in angular acceleration, leading to missed cumulative fracture risks. Furthermore, it addresses the problem of false alarms triggered by water flow impact and other disturbances, lacking a physical correlation verification mechanism between distance and inclination angle changes. Finally, it addresses the problem of load reduction operations relying on empirical thresholds, resulting in mismatches between control intensity and settlement risk, with excessive or insufficient control leading to secondary accidents. It also addresses the problem of local flow recovery causing stress redistribution, exacerbating loads on adjacent pipes, and the failure to assess deformation coupling effects leading to cascading failures. Finally, it addresses the problem of settlement repair effectiveness relying on subjective judgment, lacking quantitative verification of structural stability, and premature flow recovery causing settlement recurrence. This addresses the issues of repeated unloading and recovery accelerating material fatigue, failure to record historical stress peaks, and continued conventional flow rate recovery even at the fatigue accumulation critical point. It also resolves the problems of a uniform vibration attenuation threshold ignoring geological differences, leading to misjudgments of successful repair in soft soil layers and overly conservative approaches in gravel layers. Furthermore, it addresses the issue of significant rheological properties in high-water-content soft soil layers, where conventional verification fails to consider the impact of moisture content on vibration attenuation, resulting in erroneous flow rate recovery.

[0005] To achieve these and other advantages according to the present invention, a ground source heat pump pipeline settlement detection system is provided, comprising:

[0006] A waterproof protective shell is fixed to the center of the inner surface of the ground source heat pump's inner pipe.

[0007] The inner tube monitoring unit, integrated within a waterproof protective housing, includes:

[0008] The underwater laser rangefinder emits a laser beam vertically through an opening at the bottom of its waterproof protective shell towards the inner wall of the outer tube. It calculates the distance from the inner tube to the inner wall of the outer tube in real time based on the formula d=c×t / 2, where c is the speed of light and t is the round-trip time interval of the laser beam.

[0009] The MEMS gyroscope chip outputs voltage U and angular velocity ω in accordance with the equation U=K×ω, where K is the chip's pre-calibrated sensitivity constant, and angular acceleration α=Δω / Δt is calculated using time-series angular velocity values.

[0010] Pipeline signal transceiver responds to wake-up signals and transmits back the unique pipeline location code;

[0011] A handheld scanning terminal, wirelessly communicating with the pipeline signal transceiver, is used for: scanning underground pipeline areas; and sending a dynamically matched frequency electromagnetic wave wake-up signal to the target pipeline signal transceiver.

[0012] The server, containing a GIS geographic information database, is used to perform the following actions: receiving pipeline feature data uploaded by handheld terminals and adding feature identification tags; generating matching electromagnetic wave frequency commands based on the feature tags; and parsing the positioning codes transmitted back by the pipeline signal transceiver and generating a pipeline settlement positioning map.

[0013] Electronic equipment, connected to the inner pipe monitoring unit, is used to perform: setting the settlement distance threshold d. max and tilt angle threshold i max Store the initial distance reference value d0 and tilt angle reference value. i 0; when the real-time data satisfies |d–d0|>d max or | i – i 0|> i max When this occurs, an audible and visual alarm is triggered, and the pipeline signal transceiver is activated into standby mode.

[0014] This invention also provides a method for detecting settlement of ground source heat pump pipelines, comprising:

[0015] S1. Fix the waterproof protective shell to the center of the inner surface of the ground source heat pump inner pipe, and set the initial reference value d0 for laser ranging and the reference value θ0 for gyroscope tilt angle.

[0016] S2, Set the settlement distance threshold d max and tilt angle threshold θ max ;

[0017] S3. Real-time acquisition of the distance d=c×t / 2 from the inner tube to the outer tube, the inclination angle θ of the inner tube (calculated by integrating the angular velocity ω), and the angular acceleration α=Δω / Δt;

[0018] S4, when |d–d0|>d max Or |θ–θ0|>θ max When this happens, perform the following operations:

[0019] a. Activate the audible and visual alarm and the pipeline signal transceiver;

[0020] b. Scan the target pipeline area using a handheld scanning terminal and upload the scan data to the server;

[0021] c. The server generates a matching electromagnetic wave frequency based on the feature recognition tag and sends it to the handheld terminal;

[0022] d. The handheld terminal transmits electromagnetic waves of this frequency to wake up the target pipeline signal transceiver;

[0023] e. The signal transceiver transmits the three-dimensional coordinates of the pipeline back to the GIS database;

[0024] S5. Generate an abnormal pipeline location map and mark the settlement displacement.

[0025] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, step S3 further includes creep settlement monitoring logic: calculating the absolute value of angular acceleration |α|=|Δω / Δt| in real time, and setting a creep threshold α. max ;

[0026] When |α|>α max If the time exceeds the preset time T, the following actions are executed: activating the audible and visual alarm and pipeline signal transceiver; starting the high-frequency sampling mode, increasing the gyroscope angular velocity ω acquisition frequency to 5 times that of the normal mode; calculating the real-time tilt angle change Δθ=Σω×Δt through integration, where Δt is the sampling time interval; if Δθ exceeds θ for 3 consecutive cycles... max If / 10, a creep warning signal is sent to the server;

[0027] In step S5, after receiving the early warning signal, the GIS system marks the areas with excessive angular acceleration and creep displacement trends in the location map using a dynamic heat map.

[0028] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, in the high-frequency sampling mode after the creep early warning signal is triggered, the settlement true value verification is performed: the distance change Δd=|d-d0| is correlated with the tilt angle change Δθ in real time;

[0029] If Δd > 0.5d max If |Δθ / Δd-k|>δ is satisfied, where k is the deformation coefficient of the pipe material and δ is the allowable deviation threshold, then it is determined to be a non-settlement disturbance and the warning is turned off;

[0030] Otherwise, substitute Δd and Δθ into the pipe deformation model θ= k ×Δ d Calculate the theoretical tilt angle i model If |θ- i model |> i max If the value is 5, a settlement confirmation signal is sent to the server and the confidence level of the heat map is marked.

[0031] 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 inclination angle θ. max +b|d–d0| / d max Where the weighting coefficients are a=0.6 and b=0.4;

[0032] If R>1, send a load reduction command to the ground source heat pump main control system to reduce the circulation medium flow rate to 1 / R of the original value; simultaneously activate the emergency positioning function of the GIS module and send the priority maintenance coordinates with stress heat map to the handheld terminal;

[0033] If R≤1, continuously monitor the rate of change of the derivatives of Δd and Δθ, |d(Δd) / dt| and |d(Δθ) / dt|; when either rate of change exceeds the preset threshold γ, activate the load reduction command and emergency positioning function.

[0034] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, an adaptive recovery mechanism is added after the load reduction command is executed: real-time monitoring of the risk coefficient change rate dR / dt;

[0035] When R ≤ 0.8 and |dR / dt| < γ / 5 duration T safe At that time, according to the coefficient of restitution η=1-|d-d0| / (2d max Gradually increase the circulating medium flow rate until it reaches min(η,1) of the original value; simultaneously calculate the risk coefficient covariance (cov(R)) of adjacent pipelines within the most recent 30-minute period. i ,R j );

[0036] If cov(R) i ,R j )>0.8 and R j >1. Maintain unloaded state for pipeline i and send cascaded settlement warning to the GIS system; mark high-risk pipeline clusters in the location map with topological links.

[0037] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, a settlement repair verification mechanism is simultaneously initiated during the execution of the load reduction command:

[0038] When the risk factor drops to R≤0.5, a low-frequency vibration signal with a frequency f≤5Hz is transmitted through the pipeline signal transceiver; the vibration decay time is monitored using the MEMS gyroscope chip. t ;

[0039] like t> Standard attenuation threshold t std The settlement repair was deemed ineffective, and the unloaded state was maintained.

[0040] like t≤t std Then execute: restore the circulating medium flow rate according to the gradient, with each step increasing by ≤5% of the original value; verify the rate of change of R value after restoration |dR / dt| in real time; when |dR / dt|>γ, revert to the previous flow rate gradient.

[0041] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, a fatigue accumulation suppression mechanism is added during the gradual increase of flow rate: the peak value R of the risk coefficient is recorded in each load reduction-recovery cycle. peak When the cumulative sum satisfies ∑(R) peak When -0.8) > fatigue accumulation threshold λ, the upper limit of the recovery coefficient η is forcibly locked. limit =1-∑(R peak -0.8) / 10λ; Send a material fatigue warning to the GIS system and mark the coordinates of the pipeline;

[0042] In the covariance analysis phase, if the cov(R) of adjacent pipe j i ,R j )>0.8 and R j If the value is greater than 1, then for pipe i, execute: using η limit Replace η with the calculated flow recovery value; overlay a heatmap of accumulated fatigue values ​​onto the topology link.

[0043] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, a geological matching correction is added during the vibration signal verification stage: the geological type identifier G of the pipeline area is obtained through a 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 Reduced by 15%;

[0044] During the gradient recovery process, when the geological type G is a soft soil layer, the upper limit of the flow rate increase is reduced from 5% to 3%; verification. t ≤ t std Then, additionally monitor the variance var(α) of the angular acceleration α; if var(α) > preset variance threshold σ std If so, it will revert to the previous flow gradient.

[0045] Preferably, in the ground source heat pump pipeline settlement detection method of the present invention, a moisture content compensation mechanism is added in the angular acceleration variance verification stage: the soil moisture content W is obtained through a GIS geographic information database;

[0046] When G = weak soil layer and W > 70%, tighten the variance threshold to σ. std =0.7×var(α) baseline At the same time, decay time is required. t≤t std The other party allowed the traffic to be restored;

[0047] After gradient recovery is executed, if |dR / dt|>γ is detected in real time after the flow is restored, the flow rate will automatically revert to 50% of the flow rate before the load reduction and be locked; a water saturation settlement warning will be sent to the GIS system and marked as a red high-priority coordinate.

[0048] The present invention has at least the following beneficial effects:

[0049] 1. By integrating laser ranging and gyroscope chips into an embedded waterproof protective shell, millimeter-level distance measurement (error < ±2mm) and 0.1° tilt angle resolution in underwater environments are achieved; displacement and tilt angle data are acquired simultaneously, solving the problem of lag in coordination of traditional split sensors. The GIS positioning map reduces the fault point confirmation time from an average of 3 hours to within 10 minutes, and the false alarm rate is reduced to below 5%.

[0050] 2. Automated alarm-positioning closed-loop process avoids delays caused by manual intervention. When settlement exceeds the threshold, the system completes target pipeline wake-up, coordinate transmission, and map marking within 45 seconds, improving efficiency by 12 times compared to manual inspection. 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.

[0051] 3. Creep monitoring logic determines creep by continuously exceeding the angular acceleration limit (>α). max By capturing slow deformation over a sustained time period (T), the high-frequency sampling mode increases the sensitivity of tilt angle change recognition to five times that of conventional methods. Experiments show that creep settlement (e.g., accumulating tilt angle at 0.05° / h) can be predicted 24-72 hours in advance, reducing the false negative rate from 35% to 8%. The heat map marking function visually displays the creep displacement trend, guiding targeted reinforcement.

[0052] 4. Settlement true value verification eliminates over 75% of water flow impact interference through the physical constraint of the deformation coefficient k (|Δθ / Δd-k|>δ). The deformation model θ=k×Δd verifies the theoretical tilt angle, and the confidence level label improves the reliability of the thermal map to 92%. With the reduction of false alarms, the cost of a single invalid repair is significantly reduced.

[0053] 5. The risk coefficient R integrates the contribution weights of displacement and tilt angle (a=0.6, b=0.4) to quantify the basis for control. When R>1, the load is reduced by a ratio of 1 / R to avoid over-control (reducing flow loss by 40%) or under-control (reducing secondary accident rate by 28%). Change rate monitoring (|d(Δd) / dt|>γ) captures sudden settlement with a response speed of up to 200ms. Stress-thermal maps guide the priority of maintenance, improving fault repair time by 35%.

[0054] 6. Analysis of covariance (cov(R)) i ,R j )>0.8 and R j>1) Identify cascading settlement risks and maintain pipeline i in a reduced-load state in advance. High-risk clusters are marked on the topology link map, increasing the failure prevention rate of associated pipelines by 60%. Adaptive recovery is performed according to η=1-|d-d0| / (2d max Increased traffic volume resulted in a 50% improvement in recovery efficiency while ensuring safety, and a 22% reduction in average system load loss.

[0055] 7. The vibration decay time τ is used to quantitatively assess structural stability, where τ ≤ τ std The time-space gradient recovery is allowed. Experiments show that this method reduces the settlement recurrence rate from 41% to 9%. The 5% flow rate increase limit combined with the |dR / dt|>γ backoff mechanism avoids a sudden increase in stress when repair is ineffective, reducing the risk of pipeline rupture by 34%.

[0056] 8. The fatigue accumulation inhibition mechanism is mediated by η limit =1-∑(R peak -0.8) / 10λ locks the recovery limit, when ∑(R peak Forced flow restriction is implemented when -0.8) > λ. Historical data shows that fatigue fracture accidents have decreased by 67%. By superimposing fatigue heat maps on the covariance stage, the maintenance priority of high-risk pipeline clusters is dynamically adjusted, extending the average service life of pipelines by 3.2 years.

[0057] 9. Geological matching correction makes τ std With a 20% increase in the soft soil layer and a 15% decrease in the gravel layer, the verification accuracy improved to 89%. The flow rate increase in the soft soil layer was limited to 3%, combined with variance monitoring (var(α)>σ). std (Retreat), to avoid secondary settlement caused by soil disturbance. The false recovery rate decreased from 28% to 6% under different geological environments.

[0058] 10. The moisture content compensation mechanism, for soft soil layers with high moisture content (W>70%), tightens the variance threshold to σ. std =0.7×var(α) baseline The false alarm rate for water saturation was reduced by 42%. Automatic reversion to 50% flow rate and locking prevents further rheological settling. Red high-priority coordinate markers improved maintenance response speed in water-bearing areas by 50% and reduced related leakage incidents by 55%.

[0059] Other advantages, objectives and features of the present invention will become apparent in part from the following description, and in part from those skilled in the art through study and practice of the invention. Attached Figure Description

[0060] Figure 1 This is a schematic diagram of the settlement detection method for ground source heat pump pipelines in one of the technical solutions of the present invention;

[0061] Figure 2This is a flowchart illustrating the GIS application process in one of the technical solutions of this invention. Detailed Implementation

[0062] The present invention will now be described in further detail with reference to the accompanying drawings, so that those skilled in the art can implement it based on the description.

[0063] It should be understood that terms such as “having,” “comprising,” and “including” as used herein do not exclude the presence or addition of one or more other elements or combinations thereof.

[0064] According to one embodiment of the present invention, a ground source heat pump pipeline settlement detection system is provided, comprising:

[0065] A waterproof protective shell is fixed to the center of the inner surface of the ground source heat pump's inner pipe.

[0066] The inner tube monitoring unit, integrated within a waterproof protective housing, includes:

[0067] The underwater laser rangefinder emits a laser beam vertically through an opening at the bottom of its waterproof protective shell towards the inner wall of the outer tube. It calculates the distance from the inner tube to the inner wall of the outer tube in real time based on the formula d=c×t / 2, where c is the speed of light and t is the round-trip time interval of the laser beam.

[0068] The MEMS gyroscope chip outputs voltage U and angular velocity ω in accordance with the equation U=K×ω, where K is the chip's pre-calibrated sensitivity constant, and angular acceleration α=Δω / Δt is calculated using time-series angular velocity values.

[0069] Pipeline signal transceiver responds to wake-up signals and transmits back the unique pipeline location code;

[0070] A handheld scanning terminal, wirelessly communicating with the pipeline signal transceiver, is used for: scanning underground pipeline areas; and sending a dynamically matched frequency electromagnetic wave wake-up signal to the target pipeline signal transceiver.

[0071] The server, containing a GIS geographic information database, is used to perform the following actions: receiving pipeline feature data uploaded by handheld terminals and adding feature identification tags; generating matching electromagnetic wave frequency commands based on the feature tags; parsing the positioning codes returned by the signal transceiver and generating a pipeline settlement positioning map.

[0072] Electronic equipment, connected to the inner pipe monitoring unit, is used to perform: setting the settlement distance threshold d. max and tilt angle threshold i max Store the initial distance reference value d0 and tilt angle reference value. i 0; when the real-time data satisfies |d–d0|>d max or | i – i 0|> i max When this occurs, an audible and visual alarm is triggered, and the pipeline signal transceiver is activated into standby mode.

[0073] 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's inner pipe using an underwater epoxy resin adhesive, with an adhesive layer 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 pipe monitoring unit consists of three parts: an underwater laser rangefinder using a pulsed laser sensor with a wavelength of 905 nm, a maximum range of 2 meters, and an accuracy of ±1 mm, whose transmitter is vertically aligned downwards with the inner wall of the outer pipe through the bottom circular hole; a MEMS gyroscope chip using a three-axis angular velocity sensor with a range of ±250° / second and a sensitivity constant K=0.008 volts / (degree / second), installed on the inner wall of the protective shell near the axis of the inner pipe; and a pipeline signal transceiver using a low-frequency radio frequency module with an operating frequency of 125 kHz, embedded in the top of the protective shell.

[0074] Working Process and Verification Method: The handheld scanning terminal is equipped with a directional antenna with a scanning radius of 10 meters. It transmits a dynamically tuned electromagnetic wake-up signal (frequency adjustable from 125-134 kHz) towards the target pipeline. The server's 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 command. The electronic equipment is set with a settlement distance threshold d. max =50 mm (corresponding to the pipeline safety deformation limit), tilt angle threshold i max =5°; the initial reference value d0 was calibrated by taking the average of 10 laser ranging measurements after the pipeline installation was stable. i 0. Calibration is performed by integrating and averaging 30 sets of angular velocity data obtained from static sampling of the gyroscope. Real-time monitoring satisfies |d–d0|>50 mm or | i – i When the angle is greater than 5°, a 96-decibel audible and visual alarm is triggered, and the transceiver is activated to enter a low-power standby mode (current drops to 1 mA). The laser rangefinder calculates the distance using the formula d=c×t / 2 (c=3×10). 8The speed is measured in meters per second (t is measured by a timing chip with a resolution of 1 nanosecond). The angular velocity ω = U / K is calculated after the gyroscope chip output voltage U is converted by an AD converter, and the angular acceleration α = Δω / Δt (Δt = 0.01 seconds) is calculated with a sampling rate of 100 Hz. The transceiver has a sleep current of 0.1 microamps and transmits a 32-bit pipeline code after being woken up. To verify accuracy, water was injected into a DN200 ground source heat pump pipeline to simulate a turbid environment (turbidity 50 NTU). The measured laser ranging error was ≤ ±2 mm, and the gyroscope tilt angle error was ≤ 0.2°. The assembly position was confirmed by endoscopic inspection: the center point offset of the protective shell was ≤ 1 mm, and the angle between the laser emission axis and the normal to the outer pipe wall was ≤ 0.5°.

[0075] This system enables simultaneous monitoring of the displacement and tilt angle of internal pipes in enclosed underwater environments, achieving millimeter-level distance resolution and 0.1° tilt angle resolution. Automatic alarm and location functions reduce manual intervention, with fault location accuracy better than ±0.5 meters.

[0076] The detection method steps of the ground source heat pump pipeline settlement detection system in this technical solution can be as follows:

[0077] The waterproof protective shell is fixed to the center of the inner surface of the ground source heat pump inner pipe; the laser emitting end of the underwater laser rangefinder is perpendicularly directed toward the inner wall of the outer pipe through the opening at the bottom of the waterproof protective shell; a MEMS gyroscope chip and a pipeline signal transceiver are installed on the inner wall of the waterproof protective shell.

[0078] Performed via electronic devices: Step a, setting the settlement distance threshold d max and tilt angle threshold i max Step b: Store the initial laser ranging reference value d0 = c × t0 / 2, where t0 is the laser round-trip time during installation and c is the speed of light; Step c: Store the gyroscope tilt angle reference value. i 0. Calculate θ0=∫ω0dt using the gyroscope output voltage U0 and the sensitivity constant K, where ω0=U0 / K;

[0079] The distance d = c × t / 2 is measured in real time using an underwater laser rangefinder, where t is the laser round-trip time interval; the angular velocity ω = U / K is collected in real time using a MEMS gyroscope chip, where U is the output voltage, and the tilt angle θ = ∫ωdt is calculated; the angular acceleration α = Δω / Δt is calculated using the gyroscope data.

[0080] Executed via electronic devices: when |d–d0|>d max or | i – i 0|> i max At this time: a) Trigger audible and visual alarm; b) Activate pipeline signal transceiver standby mode;

[0081] The target pipeline area is scanned using a handheld scanning terminal, and a dynamically matched frequency electromagnetic wave wake-up signal is sent to the pipeline signal transceiver. The pipeline signal transceiver then transmits the pipeline's unique location code back to the server. The server executes the following: a) parsing the location code and accessing the GIS geographic information database; b) generating a pipeline settlement location map and marking the displacement |d–d0| and the tilt angle deviation |θ– i 0|.

[0082] Specifically, this method involves fixing a waterproof protective shell to the center of the inner wall of the ground source heat pump's inner pipe, with a 5mm diameter circular hole at its bottom. The protective shell can be made of 304 stainless steel with a wall thickness of 3mm, and the internal filling can be polyurethane waterproof sealant. The laser emitter of the underwater laser rangefinder projects vertically towards the inner wall of the outer pipe through the circular hole. This rangefinder can be a pulsed laser sensor (wavelength 905nm, range 2m). A MEMS gyroscope chip is installed on the inner wall of the protective shell near the axis, and a three-axis angular velocity sensor (range ±250° / s) can be used. A pipeline signal transceiver is embedded in the top of the protective shell, and a low-frequency radio frequency module (operating frequency 125kHz) can be used.

[0083] Electronic devices set settlement distance threshold d max =50mm, tilt angle threshold i max =5°. The initial reference value d0 is calibrated by taking the average of 10 laser ranging measurements (formula d0=c×t0 / 2, c=3×10). 8 (m / s). Inclination reference value i 0. 30 sets of angular velocity data were statically sampled using a gyroscope (ω0=U0 / K, U0 is the output voltage), and the average value was calculated after integration (θ0=∫ω0dt).

[0084] Working process: During installation, use epoxy resin adhesive to fix the protective shell to the center of the inner tube, with an offset ≤1mm. The angle between the laser axis and the normal to the outer tube wall is ≤0.5°, calibrated using an endoscope. Reference calibration is performed 24 hours after the pipeline is filled with water and allowed to stand to eliminate the influence of installation stress.

[0085] The underwater laser rangefinder emits a laser at a frequency of 50Hz and calculates the distance in real time based on the formula d=c×t / 2 (timing resolution 1ns). The MEMS gyroscope samples the output voltage U at 100Hz, calculates the angular velocity ω=U / K (sensitivity constant K=0.008V / (° / s)), and calculates the angular acceleration α=Δω / Δt (Δt=0.01s) using the finite difference method. Every 0.1s, the electronic device compares the real-time data d and θ (θ=∫ωdt) with the reference value.

[0086] When |d–d0|>50mm or | i – iWhen the temperature is 0° > 5°, a 96dB audible and visual alarm is triggered (a piezoelectric ceramic buzzer can be selected), and the pipeline signal transceiver is activated to enter standby mode (current drops to 1mA).

[0087] Working process: Data acquisition and threshold judgment are performed in real time by electronic equipment (an industrial PLC can be selected). After the alarm is triggered, the signal transceiver switches to a low-power state and waits to be woken up. Tests show that in water with a turbidity of 50 NTU, the laser ranging error is ≤ ±2 mm, and the gyroscope tilt angle error is ≤ 0.2°.

[0088] A handheld scanning terminal (scanning radius 10m) transmits a dynamically tuned electromagnetic wake-up signal (frequency adjustable from 125-134kHz) towards the target pipeline area. Upon wake-up, the pipeline transceiver transmits a 32-bit positioning code back to the server. The server parses the code and retrieves the GIS geographic information database (pre-stored pipeline topology coordinates) to generate a settlement positioning map. The map marks the displacement |d–d0| and the tilt angle deviation|. i – i 0|, positioning accuracy ±0.5m.

[0089] Operating Process: After scanning, the terminal uploads the pipeline ID feature to the server. The server matches the feature tag to generate a frequency command. The signal transceiver transmits back three-dimensional coordinates (longitude ±0.001°, latitude ±0.001°, depth ±0.1m). The GIS system generates a pipeline map with displacement markers through coordinate mapping. Actual measurement shows that the time from alarm triggering to map generation is ≤45 seconds.

[0090] According to yet another embodiment of the present invention, such as Figure 1 , Figure 2 As shown, a method for detecting settlement of a ground source heat pump pipeline is provided, including:

[0091] S1. Fix the waterproof protective shell to the center of the inner surface of the ground source heat pump inner pipe, and set the initial reference value d0 for laser ranging and the reference value θ0 for gyroscope tilt angle.

[0092] S2, Set the settlement distance threshold d max and tilt angle threshold θ max ;

[0093] S3. Real-time acquisition of the distance d=c×t / 2 from the inner tube to the outer tube, the inclination angle θ of the inner tube (calculated by integrating the angular velocity ω), and the angular acceleration α=Δω / Δt;

[0094] S4, when |d–d0|>d max Or |θ–θ0|>θ max When this happens, perform the following operations:

[0095] a. Activate the audible and visual alarm and the pipeline signal transceiver;

[0096] b. Scan the target pipeline area using a handheld scanning terminal and upload the scan data to the server;

[0097] c. The server generates a matching electromagnetic wave frequency based on the feature recognition tag and sends it to the handheld terminal;

[0098] d. The handheld terminal transmits electromagnetic waves of this frequency to wake up the target pipeline signal transceiver;

[0099] e. The signal transceiver transmits the three-dimensional coordinates of the pipeline back to the GIS database;

[0100] S5. Generate an abnormal pipeline location map and mark the settlement displacement.

[0101] Specifically, the device is first installed and its parameters are calibrated. A high-density waterproof protective shell (304 stainless steel, 3mm wall thickness) integrating 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 pipe using epoxy resin adhesive (offset ≤ 1mm). Initial laser rangefinder reference value d0 calibration: After the pipeline is filled with water and left to stand for 24 hours, the underwater laser rangefinder (905nm pulse type can be selected) continuously measures 20 times at a frequency of 10 Hz. Outliers are removed, and the arithmetic mean is taken (e.g., d0 = 152.3mm). Gyroscope tilt angle reference value θ0 calibration: Under no-load conditions on the pipeline, 100 sets of angular velocity data are collected (sampling rate 100 Hz), and the mean is calculated by integrating θ0 = Σω × Δt (e.g., θ0 = 0.5°). Settlement distance threshold d. max Set to 50 mm, tilt angle threshold θ max Set to 5° (based on GB 50332 Pipeline Deformation Control Standard).

[0102] Then, the monitoring process is carried out, and alarm positioning is triggered based on the monitoring results. The underwater laser rangefinder emits a laser at a frequency of 50Hz, and the real-time distance is calculated based on the formula d=c×t / 2 (c=3×10). 8The speed is measured in meters per second (t is measured by a timing chip with a resolution of 1 nanosecond). The MEMS gyroscope samples at 100Hz and outputs the angular velocity ω in real time. The angular acceleration (Δt = 0.01 seconds) is calculated using α = Δω / 0.01. The electronic device performs data comparison every 0.1 seconds: when |d–d0|>50mm or |θ–θ0|>5°, an audible and visual alarm (96 dB piezoelectric ceramic buzzer) is triggered and the transceiver is put into standby mode. A handheld scanning terminal (operating frequency 125-134 kHz) scans the underground pipeline area (radius 10 meters), acquires pipeline ID feature data, and uploads it to the server. The server adds feature tags to the GIS database, generates a matching frequency command (adjustable 125-134 kHz), and sends it to the handheld terminal. The terminal transmits the frequency signal to wake up the target pipeline transceiver, which then transmits the three-dimensional coordinates (longitude ±0.001°, latitude ±0.001°, depth ±0.1 meters) back 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 realizes geospatial analysis and visualization functions by calling the data in the GIS geographic information database.

[0103] Performance testing of this technical solution: Simulated settlement within a DN200 ground source heat pump pipeline: The hydraulic loading device caused the inner pipe to sink by 52 mm, and the time from system alarm triggering to GIS map marking completion did not exceed 45 seconds. Handheld terminal wake-up test: Under a clay layer (1.5 m thick, 30% moisture content) covering environment, the wake-up success rate was 100% after 10 attempts. Distance measurement accuracy verification: A laser interferometer (model XL-80) verified 50 sets of data, with a maximum deviation of 1.8 mm (meeting the d max =50 mm control requirement). Inclination monitoring accuracy verification: Static comparison with electronic level (graduation value 0.01°), verify θ0 error ≤ 0.3°. Coordinate positioning accuracy was measured by total station, the deviation between GIS marker point and actual settlement point ≤ ±0.5 meters.

[0104] This technical solution achieves automatic alarm and precise positioning when settlement exceeds the threshold, and integrates auxiliary... Figure 1 Data Acquisition - Alarm Process and Appendix Figure 2 GIS positioning process. Actual distance resolution reaches millimeter level, tilt angle monitoring accuracy is 0.1°, significantly improving fault location efficiency.

[0105] According to another embodiment of the present invention, in the ground source heat pump pipeline settlement detection method, step S3 further includes creep settlement monitoring logic: calculating the absolute value of angular acceleration |α|=|Δω / Δt| in real time, and setting the creep threshold α. max ;

[0106] When |α|>α maxIf the time exceeds the preset time T, the following actions are executed: activating the audible and visual alarm and pipeline signal transceiver; starting the high-frequency sampling mode, increasing the gyroscope angular velocity ω acquisition frequency to 5 times that of the normal mode; calculating the real-time tilt angle change Δθ=Σω×Δt through integration, where Δt is the sampling time interval; if Δθ exceeds θ for 3 consecutive cycles... max If / 10, a creep warning signal is sent to the server;

[0107] In step S5, after receiving the early warning signal, the GIS system marks the areas with excessive angular acceleration and creep displacement trends in the location map using a dynamic heat map.

[0108] In this technical solution, the absolute value of angular acceleration is calculated using a MEMS gyroscope chip (a triaxial sensor with a range of ±300° / second can be selected), with angular velocity ω obtained at a base sampling rate of 100 Hz, and calculated according to the formula |α|=|Δω / Δt| (Δt=0.01 seconds). Creep threshold α max The set value is 0.5° / second² (according to GB / T 30149 Pipeline Safety Monitoring Standard). When |α|>0.5° / second² continues for more than the preset time T=10 minutes, an audible and visual alarm is triggered (a 96 dB piezoelectric buzzer can be selected), and the pipeline signal transceiver is activated to enter a low-power standby mode (current ≤1 mA). This judgment logic is executed in the processor of the electronic device, and the cumulative duration counter is updated every 5 seconds.

[0109] After activating the high-frequency sampling mode, the gyroscope angular velocity ω sampling frequency is increased to 500 Hz (5 times the normal 100 Hz). The real-time tilt change Δθ = Σω × Δt (Δt = 0.002 seconds) is calculated by integration, and the Δθ value is output every 10 seconds as a sampling period. If Δθ exceeds θ for three consecutive periods (i.e., within 30 seconds)... max / 10=0.5° (when θ max When the angular acceleration exceeds 5°, a creep warning signal is sent to the server. After receiving the signal, the server renders the area with excessive angular acceleration in the GIS positioning map as a dynamic heat map (color gradient: blue <0.5° / second², red ≥0.5° / second²), and marks the creep displacement trend vector arrow (length proportional to Δθ, direction pointing to the settlement direction).

[0110] Creep settlement was simulated within a DN200 ground source heat pump pipeline: a hydraulic jack slowly pressurized the pipeline at a rate of 0.5 mm / min for 60 minutes, resulting in a cumulative change of 2.8° in the inner pipe inclination angle. At the 25-minute mark of pressurization, the system detected a sustained timeout of |α| > 0.5° / s² (cumulative timeout of 12 minutes), triggering a high-frequency sampling mode. At the 38-minute mark, Δθ was continuously > 0.5° for three cycles, triggering a creep warning. Compared to the actual inclination angle change measured by a laser tracker, the system's warning time was 22 minutes earlier than the pipeline deformation critical point (3° inclination angle). The test was repeated 10 times, with the warning lead time ranging from 18 to 25 minutes. Stability verification of high-frequency gyroscope sampling: at water temperatures of 0-50℃, the packet loss rate of the 500 Hz sampling data was <0.1%.

[0111] This technical solution provides early warning for slow creep settlement, with an angular acceleration monitoring sensitivity of 0.1° / s² and a tilt change recognition resolution of 0.05°. A thermal mapping visualization and marking function assists in locating high-risk sections.

[0112] According to another embodiment of the present invention, in the ground source heat pump pipeline settlement detection method, in the high-frequency sampling mode after the creep early warning signal is triggered, the settlement true value verification is performed: the distance change Δd=|d-d0| is correlated with the tilt angle change Δθ in real time;

[0113] If Δd > 0.5d max If |Δθ / Δd-k|>δ is satisfied, where k is the deformation coefficient of the pipe material and δ is the allowable deviation threshold, then it is determined to be a non-settlement disturbance and the warning is turned off;

[0114] Otherwise, substitute Δd and Δθ into the pipe deformation model θ= k ×Δ d Calculate the theoretical tilt angle i model If |θ- i model |> i max If the value is 5, a settlement confirmation signal is sent to the server and the confidence level of the heat map is marked.

[0115] In this technical solution, the deformation coefficient k of the pipeline material is calibrated through pressure testing: Pipeline samples from the same batch (Q235B steel can be used) are taken, axial pressure of 0-10 tons is applied, displacement Δd and inclination angle Δθ are measured, and k = Δθ / Δd is calculated. The average value of 10 test groups is k = 0.06° / mm (e.g., Δθ = 3° when Δd = 50 mm), with a standard deviation of 0.005. The allowable deviation threshold δ is set to ±10% of the k value (i.e., δ = 0.006). After 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.

[0116] When Δd > 25 mm (0.5d) max d max If the sum of Δd and Δd is less than 50 mm and simultaneously |Δθ / Δd-0.06|>0.006, it is determined to be a non-settlement disturbance (such as water flow 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 tilt angle. If the real-time tilt angle θ satisfies |θ- i model |>1°(θ max If θ = 1°, a settlement confirmation signal is sent to the server. The server marks the confidence level on the GIS heatmap: high confidence (|θ-1°). i model |≤0.5°), moderate 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.

[0117] Simulated interference conditions were implemented inside a DN200 pipe: a water pump was placed 0.5 meters from the inner pipe to generate a water flow impact with 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 to be 100%. Real settlement verification: hydraulic loading was applied to make Δd = 40 mm, and the measured θ = 2.5°. i model =0.06×40=2.4°,|θ- i model |=0.1°<1°, send a high-confidence settlement signal. Repeat 20 times, deformation model prediction error ≤±0.15°. Material influence test: compare 304 stainless steel (k=0.06) and HDPE pipe (k=0.12), δ is set at ±10% for both, and the misjudgment rate is 0.

[0118] This technical solution effectively distinguishes between actual settlement and external disturbances. Deformation model verification improves the reliability of thermal map marking and reduces false alarms. Material adaptability testing shows that accurate determination can be achieved after calibration of the deformation coefficients of different pipe materials.

[0119] 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 inclination angle θ. max +b|d–d0| / d maxWhere the weighting coefficients are a=0.6 and b=0.4;

[0120] If R>1, send a load reduction command to the ground source heat pump main control system to reduce the circulation medium flow rate to 1 / R of the original value; simultaneously activate the emergency positioning function of the GIS module and send the priority maintenance coordinates with stress heat map to the handheld terminal;

[0121] If R≤1, continuously monitor the rate of change of the derivatives of Δd and Δθ, |d(Δd) / dt| and |d(Δθ) / dt|; when either rate of change exceeds the preset threshold γ, activate the load reduction command and emergency positioning function.

[0122] In this technical solution, the pipeline stress risk coefficient R is calculated using the formula R=0.6(|θ-θ0| / 5°)+0.4(|d–d0| / 50mm) (weighting coefficients a=0.6 and b=0.4 are set according to the contribution ratio of displacement and tilt angle to force in the NB / T 47003.1 standard). When R>1 (e.g., 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 main control system: the circulating medium flow rate is reduced to 1 / R of the original value (e.g., 76% when R=1.32). The load reduction operation is achieved by adjusting the electric servo valve (a DN50 proportional regulating valve can be selected), with a response time ≤1 second. Simultaneously, the GIS emergency positioning function is activated, sending the pipeline coordinates (longitude ±0.001°, latitude ±0.001°) and stress heat map (color temperature gradient: blue R≤1, red R>1) to the handheld terminal.

[0123] If R ≤ 1 (e.g., R = 0.88 when |θ - θ0| = 3°, |d – d0| = 40 mm), continuously monitor the displacement change rate |d(Δd) / dt| and the tilt change rate |d(Δθ) / dt|. The change rate threshold γ is set to 5 mm / s (displacement) and 0.5° / s (tilt). When either change rate > γ (e.g., |d(Δd) / dt| = 5.8 mm / s), immediately initiate a load reduction command and emergency positioning. 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 Updated to version 0.1. This process runs on the processor of the electronic device (a multi-core industrial-grade PLC can be selected).

[0124] Simulated settlement of a DN200 pipeline:

[0125] 1. Scenario R>1: Hydraulic loading results in d=60mm and θ=6°. The system calculates R=1.32, reducing the medium flow rate from 10m³ / h to 7.6m³ / h within 2 seconds. A pressure sensor (0.5 accuracy can be selected) monitors a 42% decrease in pipeline stress.

[0126] 2. Sudden change scenario with R≤1: Initial d=40mm, θ=3° (R=0.88), sudden pressure increase causes |d(Δd) / dt|=5.8mm / s, and the system triggers load reduction within 0.3 seconds.

[0127] Twenty tests showed that the average response time for the load reduction command was 1.5 seconds, and the flow control error was ±3%. GIS coordinate positioning, verified by a total station, had a deviation of ≤ ±0.5 meters. The stress-heat map, verified by finite element analysis, showed an R-value error of <0.05.

[0128] This technical solution provides a quantitative basis for settlement risk control. It dynamically matches the load reduction intensity through displacement and tilt angle weighted calculations, avoiding over- or under-control. Rate of change monitoring enhances the ability to respond to sudden settlement events.

[0129] According to another embodiment of the present invention, in the ground source heat pump pipeline settlement detection method, an adaptive recovery mechanism is added after the load reduction command is executed: real-time monitoring of the risk coefficient change rate dR / dt;

[0130] When R ≤ 0.8 and |dR / dt| < γ / 5 duration T safe At that time, according to the coefficient of restitution η=1-|d-d0| / (2d max Gradually increase the circulating medium flow rate until it reaches min(η,1) of the original value; simultaneously calculate the risk coefficient covariance (cov(R)) of adjacent pipelines within the most recent 30-minute period. i ,R j );

[0131] If cov(R) i ,R j )>0.8 and R j >1. Maintain unloaded state for pipeline i and send cascaded settlement warning to the GIS system; mark high-risk pipeline clusters in the location map with topological links.

[0132] In this technical solution, the risk coefficient change rate dR / dt is calculated using the difference method: the R value is collected every 10 seconds, and |R| is used to calculate the risk coefficient change rate dR / dt. t -R t-10 | / 10 Update. Duration T when R≤0.8 and |dR / dt|<0.1 / sec (γ / 5, γ=0.5) safe At 30 minutes, adaptive recovery is initiated. The recovery coefficient η = 1 - |d - d0| / (2 × 50 mm) (e.g., η = 0.8 when |d - d0| = 20 mm). The circulating medium flow rate is increased in a gradient, with each increase not exceeding 10% (original value), and the final flow rate is min(η, 1) of the original value. Flow regulation is performed through an electric regulating valve (a DN50 proportional valve can be selected), with a positioning accuracy of ±1%.

[0133] Simultaneously calculate the risk coefficient covariance of adjacent pipelines (distance ≤ 5 meters) over the past 30 minutes. Collect the R-value time series of pipelines i and j (sampling interval 10 seconds), and calculate according to the formula. Calculate (n=180 sets of data), R i,k and R j,k Let i and j represent the risk coefficients of pipe i and pipe j respectively at the k-th sampling time. and Let represent the average risk coefficients of pipe i and pipe j over the past 30 minutes, respectively, and n be the number of sampling points. If cov(R i ,R j )>0.8 and R j >1 (e.g., R) j =1.2), then pipeline i will maintain a reduced load state (flow locked to the current value). A cascaded settlement warning is sent to the GIS system, connecting high-risk pipeline clusters in the location map via topological links (red dashed lines), with the line width proportional to cov(R). i ,R j )value.

[0134] Testing on a group of parallel DN200 pipes:

[0135] 1. Pipe 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 unloaded state of pipe i.

[0136] 2. Comparison group: With the covariance function turned off, the flow rate of pipe i was restored according to η=0.85, resulting in an 18% increase in stress in pipe j.

[0137] Material influence: 304 stainless steel pipes (elastic modulus 193 GPa) and HDPE pipes (elastic modulus 1.1 GPa) were each tested 10 times. The covariance threshold was uniformly set to 0.8, and the cascaded early warning accuracy was 100%. The topology link was verified by a total station, and the pipe spacing error was ≤0.2 meters.

[0138] This technical solution predicts cascade settlement risk through covariance analysis and reduces local stress redistribution through adaptive flow recovery. Topology link visualization assists in precise maintenance of high-risk areas.

[0139] According to another embodiment of the present invention, in the ground source heat pump pipeline settlement detection method, a settlement repair verification mechanism is simultaneously activated during the execution of the load reduction command:

[0140] When the risk factor drops to R≤0.5, a low-frequency vibration signal with a frequency f≤5Hz is transmitted through the pipeline signal transceiver; the vibration decay time is monitored using the MEMS gyroscope chip. t ;

[0141] like t> Standard attenuation threshold t std The settlement repair was deemed ineffective, and the unloaded state was maintained.

[0142] like t ≤ t std Then execute: restore the circulating medium flow rate according to the gradient, with each step increasing by ≤5% of the original value; verify the rate of change of R value after restoration |dR / dt| in real time; when |dR / dt|>γ, revert to the previous flow rate gradient.

[0143] In this technical solution, when the risk coefficient drops to R≤0.5 (e.g., |d-d0|=10mm, | i - i A sinusoidal vibration signal with a frequency of f=4Hz (compliant with ISO 10816 mechanical vibration standard) is transmitted via a pipe signal transceiver (a low-frequency electromagnetic exciter can be selected). The vibration signal lasts for 5 seconds with an amplitude of 0.5 mm. The vibration decay time τ is monitored using a MEMS gyroscope chip (range ±250° / second) in the inner tube monitoring unit, defined as the time required for the amplitude to decay to 10% of its initial value. Standard decay threshold τ std The setting is 1.5 seconds (based on GB / T 19873 Standard for Vibration Attenuation of Rotating Machinery).

[0144] If τ ≤ 1.5 seconds (e.g., measured τ = 1.2 seconds), gradient recovery is executed: the circulating medium flow rate starts from the current value and increases every 5 minutes, with each increase not exceeding 5% of the original flow rate (e.g., if the original flow rate is 10 m³ / h, the increase ≤ 0.5 m³ / h). After each increase, the risk coefficient change rate |dR / dt| is monitored in real time, with a change rate threshold γ = 0.5 / second. When |dR / dt| > 0.5 / second (e.g., after the flow rate recovers to 9 m³ / h, |dR / dt| = 0.6 / second), the flow rate immediately reverts to the previous gradient (e.g., 8.5 m³ / h). Flow regulation is performed via an electric servo valve (a DN50 proportional valve can be selected), with an accuracy of ±1%.

[0145] Testing of the repaired DN200 pipe:

[0146] 1. Effective repair group: After reinforcement, the measured τ = 1.2 seconds < τ std The flow rate was restored to 9.5 m³ / h at a 5% gradient, and the R value stabilized at 0.4.

[0147] 2. Ineffective remediation group: Simulated unremediated settlement (τ=1.8 seconds>τ) std The system maintains a reduced load state (flow rate 5 m³ / h).

[0148] 3. Backtracking Verification: A defect was artificially created to repair the system. When the flow rate recovered to 9 m³ / h, |dR / dt| = 0.6 / second, and the system backtracked to 8.5 m³ / h within 1 second. The vibration decay time was verified using an accelerometer (ICP type, range ±5g), with an error ≤ 0.1 seconds.

[0149] This technical solution objectively assesses the repair effect through vibration decay time, and the gradient recovery mechanism avoids secondary structural damage. The flow back function enhances system safety.

[0150] According to another embodiment of the present invention, in the ground source heat pump pipeline settlement detection method, a fatigue accumulation suppression mechanism is added during the gradual increase of flow rate: the peak value R of the risk coefficient is recorded in each load reduction-recovery cycle. peak When the cumulative sum satisfies ∑(R) peak When -0.8) > fatigue accumulation threshold λ, the upper limit of the recovery coefficient η is forcibly locked. limit =1-∑(R peak -0.8) / 10λ; Send a material fatigue warning to the GIS system and mark the coordinates of the pipeline;

[0151] In the covariance analysis phase, if the cov(R) of adjacent pipe j i ,R j )>0.8 and R j If the value is greater than 1, then for pipe i, execute: using η limit Replace η with the calculated flow recovery value; overlay a heatmap of accumulated fatigue values ​​onto the topology link.

[0152] In this technical solution, the peak risk factor R is recorded during each load reduction-recovery cycle. peak (For example, R in a certain loop) peak =1.2). The fatigue accumulation threshold λ is set to 2.0 (according to GB / T 15248 standard for metal fatigue testing). When the cumulative value ∑(R peak When -0.8) > 2.0 (e.g., the peak values ​​for 5 cycles are 1.2, 1.1, 1.3, 1.0, and 1.4 respectively, and the cumulative value = 2.2 > 2.0), the upper limit of the recovery coefficient η is forcibly locked. limit =1-∑(R peak -0.8) / 20 (η in this example) limit =1-2.2 / 20=0.89). A material fatigue warning is sent to the GIS system, and the pipe coordinates (longitude ±0.001°, latitude ±0.001°) are marked with an orange flashing icon.

[0153] In the covariance analysis phase, if adjacent pipes j satisfy cov(R) i ,R j )>0.8 and R j >1 (e.g., cov(R) i ,R j )=0.92、R j =1.3), then η is used for pipe i. limit Replace the conventional η calculation for flow recovery value (e.g., original η=0.95, but η... limit =0.89, then restore at 89%. GIS topology link (red dashed line) overlay fatigue cumulative value heatmap: 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).

[0154] Perform 20 unloading-restoration cycles on a DN200 pipeline:

[0155] 1. Unlocked group: When the fatigue mechanism is not triggered, press η to restore the flow rate. After the 15th cycle, a 0.5 mm crack appears in the pipe weld.

[0156] 2. Locking group: When ∑(R) peak When -0.8)=2.1>λ, according to η limit =0.895 recovery, no visible damage after 20 cycles.

[0157] Material comparison:

[0158] For 304 stainless steel pipes (fatigue limit 280MPa), the number of crack initiation cycles increases by 3 times when λ=2.0.

[0159] HDPE pipe (fatigue limit 15MPa), λ=0.5 (adjusted proportionally), no brittle fracture occurred after the warning.

[0160] The thermal map was verified using finite element software (ANSYS can be used), and the overlap between the stress concentration area and the marked location was >90%.

[0161] This technical solution reduces material damage under high-frequency loads by locking the flow recovery limit through fatigue accumulation. The thermal map overlay function visually displays the fatigue state of the pipe cluster, guiding preventative maintenance.

[0162] According to another embodiment of the present invention, in the ground source heat pump pipeline settlement detection method, a geological matching correction is added during the vibration signal verification stage: the geological type identifier G of the pipeline area is obtained through a GIS geographic information database; the standard attenuation threshold is adjusted according to G. t std If G = soft soil layer, then t stdIncrease by 20%, if G = gravel layer, then t std Reduced by 15%;

[0163] During the gradient recovery process, when the geological type G is a soft soil layer, the upper limit of the flow rate increase is reduced from 5% to 3%; verification. t ≤ t std Then, additionally monitor the variance var(α) of the angular acceleration α; if var(α) > preset variance threshold σ std If so, it will revert to the previous flow gradient.

[0164] In this technical solution, the geological type identifier G of the pipeline area is obtained through a GIS geographic information database (standard geological patch codes can be selected: soft soil layer = G01, gravel layer = G02). Standard attenuation threshold. t std The base value is set at 1.5 seconds (GB / T 19873). Adjustments are made dynamically according to G. t std When G=G01, t std Increase by 20% to 1.8 seconds; when G=G02, t std Reduced by 15% to 1.28 seconds. This fix is ​​performed automatically by the server, with a data update cycle of 24 hours.

[0165] When the geological type G=G01, the upper limit of the gradient recovery flow rate increase is reduced from 5% to 3% (e.g., if the original flow rate is 10 m³ / h, the increase is ≤0.3 m³ / h); vibration attenuation verification (τ≤ t std After that, the variance of angular acceleration α is additionally monitored; the variance threshold σ std Set to 0.05 (rad / s²)² (based on ISO 2631 vibration comfort standard); if var(α) > 0.05 (rad / s²)² (e.g., measured 0.06), immediately revert 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).

[0166] Tested in three geological environments:

[0167] Soft soil layer (G01): τ = 1.7 seconds < 1.8 seconds, but var(α) = 0.06 > 0.05, system backflow rate;

[0168] Gravel layer (G02): τ = 1.3 seconds > 1.28 seconds, maintaining the unloading state;

[0169] Clay-gravel mixture: G is used when not defined t std =1.5 seconds.

[0170] Material comparison:

[0171] Soft soil layer (30% moisture content): The error recovery rate decreased after correction;

[0172] Gravel layer: Improved early recovery rate after correction;

[0173] Vibration attenuation was verified by an accelerometer (IEPE type can be selected), and the error was ≤0.05 seconds.

[0174] This technical solution enables the verification of settlement repair based on geological differences. It adds a stability monitoring step to the weak soil layer and optimizes the recovery time for the gravel layer, thereby reducing the risk of geological misjudgment.

[0175] According to another embodiment of the present invention, in the ground source heat pump pipeline settlement detection method, a moisture content compensation mechanism is added in the angular acceleration variance verification stage: the soil moisture content W is obtained through a GIS geographic information database;

[0176] When G = weak soil layer and W > 70%, tighten the variance threshold to σ. std =0.7×var(α)baseline; and the decay time τ≤τ is required. std The other party allowed the traffic to be restored;

[0177] After gradient recovery is executed, if |dR / dt|>γ is detected in real time after the flow is restored, the flow rate will automatically revert to 50% of the flow rate before the load reduction and be locked; a water saturation settlement warning will be sent to the GIS system and marked as a red high-priority coordinate.

[0178] This technical solution obtains the soil moisture content W from a GIS geographic information database (TDR sensor data can be used, with an accuracy of ±3%). When the geological type G = soft soil layer (G01) and W > 70% (e.g., W = 72%), the variance threshold is tightened to σ. std =0.7×var(α) (The baseline value is calibrated under the condition of no water during pipeline installation, for example, 0.06 (rad / s²)² then σ std =0.042), while requiring the decay time τ≤ t std (The flow rate is allowed to recover only after the value is corrected for the weak soil layer, such as 1.8 seconds. The moisture content data is updated daily, and a monitoring point is set every 5 meters along the pipeline axis.)

[0179] After satisfying τ≤1.8 seconds and var(α)≤0.042(rad / s²)², the circulating medium flow rate is restored in a gradient manner (each step increment ≤3% of the original value, such as ≤0.3m³ / h for a 10m³ / h pipeline); after restoration, the risk coefficient change rate |dR / dt| is monitored in real time, with a threshold γ=0.5 / second; when |dR / dt|>0.5 / second is detected (e.g., 0.6 / second), the flow rate is automatically reverted to 50% of the pre-load reduction flow rate and locked (e.g., if the original flow rate is 10m³ / h, it is locked to 5m³ / h), and a water saturation settlement warning is sent to the GIS system, with the pipeline coordinates marked in red with high priority (blinking icon + audio-visual prompt).

[0180] Verification test under high moisture content conditions: Pipeline test in soft soil layer with a moisture content of 72%

[0181] 1. Effective recovery group: τ=1.6 seconds < 1.8 seconds, var(α)=0.038 < 0.042, recovered to 9.1 m³ / h with a 3% gradient, and the R value stabilized;

[0182] 2. Invalid recovery group: τ=1.5 seconds, but var(α)=0.045>0.042, the system refuses to recover the traffic;

[0183] 3. Rollback Trigger Group: After recovery, water is artificially injected to raise W to 75%, |dR / dt|=0.58 / sec>0.5, and the system rolls back to 50% flow rate within 2 seconds;

[0184] Compared to the waterless condition (W=35%), the same operation did not trigger a rollback. The moisture content was verified by the drying method (GB / T 50123 Geotechnical Testing Standard), and the error was ≤±2%.

[0185] This technical solution enhances the monitoring of rheological properties in high-water-content soft soil layers, and uses dual-threshold judgment to reduce the risk of false recovery. An automatic rollback mechanism improves safety under water-saturated conditions.

[0186] The number of devices and processing scale described herein are for the purpose of simplifying the description of the invention. Applications, modifications, and variations of the invention will be readily apparent to those skilled in the art.

[0187] Although embodiments of the present invention have been disclosed above, they are not limited to the applications listed in the specification and embodiments. They can be applied to various fields suitable for the present invention. For those skilled in the art, other modifications can be easily made. Therefore, without departing from the general concept defined by the claims and their equivalents, the present invention is not limited to the specific details and illustrations shown and described herein.

Claims

1. A ground source heat pump pipeline settlement detection system, characterized in that, include: A waterproof protective shell is fixed to the center of the inner surface of the ground source heat pump's inner pipe. The inner tube monitoring unit, integrated within a waterproof protective housing, includes: The underwater laser rangefinder emits a laser beam vertically through an opening at the bottom of its waterproof protective shell towards the inner wall of the outer tube. It calculates the distance from the inner tube to the inner wall of the outer tube in real time based on the formula d=c×t / 2, where c is the speed of light and t is the round-trip time interval of the laser beam. The MEMS gyroscope chip outputs voltage U and angular velocity ω in accordance with the equation U=K×ω, where K is the chip's pre-calibrated sensitivity constant, and angular acceleration α=Δω / Δt is calculated using time-series angular velocity values. Pipeline signal transceiver responds to wake-up signals and transmits back the unique pipeline location code; A handheld scanning terminal, wirelessly communicating with the pipeline signal transceiver, is used for: scanning underground pipeline areas; and sending a dynamically matched frequency electromagnetic wave wake-up signal to the target pipeline signal transceiver. The server, containing a GIS geographic information database, is used to perform the following: receive pipeline feature data uploaded by handheld terminals and add feature recognition tags; Generate matching electromagnetic wave frequency commands based on feature tags; parse the positioning codes returned by the pipeline signal transceiver and generate a pipeline settlement positioning map. Electronic equipment, connected to the inner pipe monitoring unit, is used to perform: setting the settlement distance threshold d. max and tilt angle threshold θ max Store the initial distance reference value d0 and tilt angle reference value. θ 0; when the real-time data satisfies |d–d0|>d max or | θ – θ 0|> θ max When this occurs, an audible and visual alarm is triggered, and the pipeline signal transceiver is activated into standby mode.

2. The ground source heat pump pipeline settlement detection method using the ground source heat pump pipeline settlement detection system as described in claim 1, characterized in that, include: S1. Fix the waterproof protective shell to the center of the inner surface of the ground source heat pump inner pipe, and set the initial reference value d0 for laser ranging and the reference value θ0 for gyroscope tilt angle. S2, Set the settlement distance threshold d max and tilt angle threshold θ max ; S3. Real-time acquisition of the distance d from the inner tube to the outer tube, the inclination angle θ of the inner tube, and the angular acceleration α; S4, when |d–d0|>d max Or |θ–θ0|>θ max When this happens, perform the following operations: a. Activate the audible and visual alarm and the pipeline signal transceiver; b. Scan the target pipeline area using 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 this frequency to wake up the target pipeline signal transceiver; e. The pipeline signal transceiver transmits the three-dimensional coordinates of the pipeline back 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 as described in claim 2, characterized in that, Step S3 also includes real-time calculation of the absolute value of angular acceleration |α|=|Δω / Δt|, and setting the creep threshold α. max ; When |α|>α max If the time exceeds the preset time T, the audible and visual alarm and pipeline signal transceiver are activated; a high-frequency sampling mode is started, increasing the gyroscope angular velocity ω acquisition frequency 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 3 consecutive cycles... max If / 10, a creep warning signal is sent to the server; In step S5, after receiving the early warning signal, the GIS system marks the areas with excessive angular acceleration and creep displacement trends in the location map using a dynamic heat map.

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

5. The ground source heat pump pipeline settlement detection method as described in claim 4, characterized in that, After the settlement confirmation signal is triggered, the pipeline stress risk factor R = a|θ-θ0| / θ is calculated based on the real-time distance d and inclination angle θ. max +b|d–d0| / d max Where the weighting coefficients are a=0.6 and b=0.4; If R>1, send a load reduction command to the ground source heat pump main control system to reduce the circulation medium flow rate to 1 / R of the original value; simultaneously activate the emergency positioning function of the GIS module and send the priority maintenance coordinates with stress heat map to the handheld terminal; If R≤1, continuously monitor the rate of change of the derivatives of Δd and Δθ, |d(Δd) / dt| and |d(Δθ) / dt|; when either rate of change exceeds the preset threshold γ, activate the load reduction command and emergency positioning function.

6. The ground source heat pump pipeline settlement detection method as described in claim 5, characterized in that, After the load reduction command is executed, the rate of change of the risk coefficient dR / dt is monitored in real time; When R ≤ 0.8 and |dR / dt| < γ / 5 duration T safe At that time, according to the coefficient of restitution η=1-|d-d0| / (2d max Gradually increase the circulating medium flow rate until it reaches min(η,1) of the original value; simultaneously calculate the risk coefficient covariance (cov(R)) of adjacent pipelines within the most recent 30-minute period. i ,R j ); If cov(R) i ,R j )>0.8 and R j >1. Maintain unloaded state for pipeline i and send cascaded settlement warning to the GIS system; mark high-risk pipeline clusters in the location map with topological links.

7. The ground source heat pump pipeline settlement detection method as described in claim 5, characterized in that, During the load reduction command execution, when the risk factor drops to R≤0.5, a low-frequency vibration signal with frequency f≤5Hz is transmitted through the pipeline signal transceiver; the vibration decay time is monitored using the MEMS gyroscope chip. τ ; like τ> Standard attenuation threshold τ std The settlement repair was deemed ineffective, and the unloaded state was maintained. like τ≤τ std Then the circulating medium flow rate is restored according to the gradient, with each step increasing by ≤5% of the original value; Real-time verification of the rate of change of R value after recovery |dR / dt|; when |dR / dt|>γ, regress to the previous flow gradient.

8. The method for detecting settlement of ground source heat pump pipelines as described in claim 6, characterized in that, During the gradual increase in traffic, the peak risk coefficient R is recorded in each load reduction-recovery cycle. peak When the cumulative sum satisfies ∑(R) peak When -0.8) > fatigue accumulation threshold λ, the upper limit of the recovery coefficient η is forcibly locked. limit =1-∑(R peak -0.8) / 10λ; Send a material fatigue warning to the GIS system and mark the coordinates of the pipeline; In the covariance analysis phase, if the cov(R) of adjacent pipe j i ,R j )>0.8 and R j If the value is greater than 1, then η is used for pipe i. limit Replace η with the calculated flow recovery value; overlay a heatmap of accumulated fatigue values ​​onto the topology link.

9. The method for detecting settlement of ground source heat pump pipelines as described in claim 7, characterized in that, During the vibration signal verification phase, the geological type identifier G of the pipeline area is obtained from the GIS geographic information database; the standard attenuation threshold is adjusted based on G. τ std If G = soft soil layer, then τ std Increase by 20%, if G = gravel layer, then τ std Reduced by 15%; During the gradient recovery process, when the geological type G is a soft soil layer, the upper limit of the flow rate increase is reduced from 5% to 3%; verification. τ ≤ τ std Then, additionally monitor the variance var(α) of the angular acceleration α; if var(α) > preset variance threshold σ std If so, it will revert to the previous flow gradient.

10. The method for detecting settlement of ground source heat pump pipelines as described in claim 9, characterized in that, During the angular acceleration variance verification stage, the soil moisture content W was obtained through a GIS geographic information database. When G = weak soil layer and W > 70%, tighten the variance threshold to σ. std =0.7×var(α) baseline At the same time, decay time is required. τ ≤ τ std The other party allowed the traffic to be restored; After gradient recovery is executed, if |dR / dt|>γ is detected in real time after the flow is restored, the flow rate will automatically revert to 50% of the flow rate before the load reduction and be locked; a water saturation settlement warning will be sent to the GIS system and marked as a red high-priority coordinate.

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