Fracturing Pump Operation Fault Detection Method, System, and Device, and Storage Medium

Abstract

A fracturing pump detection method, system, and device, and a storage medium, relating to the technical field of fracturing devices. The fracturing pump detection method includes: detecting stress information in a pull rod of a fracturing pump through a sensor installed at a power end of the fracturing pump, the sensor being isolated from fracturing liquid displaced by the fracturing pump; determining pump cavity liquid pressure information of the fracturing pump according to the stress information of the pull rod; determining phase information of a plunger corresponding to the stress information of the pull rod; and determining a detection result of the fracturing pump according to the pump cavity liquid pressure information and phase information of the plunger.

Description

TECHNICAL FIELD

The present disclosure 1 relates generally to the technical field of fracturing devices, and more specifically to a fracturing pump operation fault detection method, system, and device, and a storage medium. The operation fault, for example, may include various leakages in the fracturing pump.

BACKGROUND

At present, after the production of an oil well reaches a certain phase, because the permeability of unextracted crude oil in the oil well gradually decreases, it becomes difficult to extract the crude oil in the oil well, and the yield of the oil well also gradually decreases. To improve the yield of the oil well, fracturing operations may need to be performed on the oil well. In a fracturing operation, a fracturing pump is mainly used to deliver a liquid mixed with sand into a stratum at an extremely high pressure, to improve a flowing condition of the crude oil in the oil well, so that the crude oil in the oil well flows more easily and becomes extractable.

The hydraulic end is an important part of the fracturing pump system, and its main function is to pressurize the low-pressure fluid (for example, <1 MPa) to the high-pressure fluid (for example, >10 MPa). The structure of the hydraulic end includes a valve assembly, a packing assembly, plungers, an end cover assembly, and other parts. The valve assembly can include upper and lower valves, valve bases, valve springs, and the like. The valve assembly is a main hydraulic component of the hydraulic end, and its main function is to realize one-way flow of the medium. The lower valve is opened during liquid suction and closed during pressurization and liquid discharge in the hydraulic end, and the upper valve is closed during liquid suction and opened during pressurization and liquid discharge in the hydraulic end. The upper and lower valves are opened and closed repeatedly during operation, which determines that they are vulnerable parts, and are prone to pits and cracks caused by impact and particle wear. As a result, seal fails and the function of the hydraulic end is abnormal.

Currently, there is a lack of valve leakage detection means in the market. Usually, regular inspections are performed or replacement is performed after the function of the hydraulic end is found to be obviously abnormal. Consequently, a leaked valve is not replaced in time, resulting in abnormal wear or cracking of a component adjacent to the valve. Eventually, the hydraulic end is scrapped as a whole.

However, because the liquid mixed with sand in the fracturing pump tends to strongly corrode its body and its high and low pressure sealing members, the fracturing pump, when being used, is prone to washout, spraying, bursting, and the like, which may severely affect the physical safety of on-site operators. Therefore, when the fracturing pump operates, monitoring and diagnosis of faulty conditions may need to be performed with respect to an operation status of the fracturing pump implemented as, e.g., a high pressure plunger pump.

SUMMARY

According to a first aspect, the present disclosure provides a fracturing pump detection method, including: detecting stress information of a pull rod of a fracturing pump through a sensor at a power end of the fracturing pump; determining pump cavity liquid pressure information of the fracturing pump according to the stress information of the pull rod; and determining a detection result of the fracturing pump according to the pump cavity liquid pressure information and phase information of a plunger corresponding to the stress information of the pull rod.

In some implementations, the sensor at the power end includes a tension sensor mounted at the pull rod of the fracturing pump, and the detecting stress information of a pull rod of a fracturing pump through a sensor at a power end of the fracturing pump includes: obtaining end tension information of the pull rod detected by the tension sensor; and determining the stress information of the pull rod based on the end tension information of the pull rod and preset end cross-sectional area information of the pull rod corresponding to the fracturing pump.

In some implementations, the sensor at the power end includes a strain sensor mounted at the pull rod of the fracturing pump, and the detecting stress information of a pull rod of a fracturing pump through a sensor at a power end of the fracturing pump includes: obtaining end strain information of the pull rod detected by the strain sensor; and determining the stress information of the pull rod based on the end strain information of the pull rod, preset elastic modulus information of a material of the pull rod corresponding to the fracturing pump, and the preset end cross-sectional area information of the pull rod corresponding to the fracturing pump.

In some implementations, the determining pump cavity liquid pressure information of the fracturing pump according to the stress information of the pull rod includes: obtaining piston cross-sectional area information of the fracturing pump for the stress information of the pull rod; and performing calculation based on the piston cross-sectional area information and the stress information of the pull rod, to obtain the pump cavity liquid pressure information of the fracturing pump.

In some implementations, the determining a detection result of the fracturing pump according to the pump cavity liquid pressure information and phase information of a plunger corresponding to the stress information of the pull rod includes: determining the phase information of the plunger corresponding to the stress information of the pull rod; detecting whether the pump cavity liquid pressure information matches the phase information of the plunger; determining liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the phase information of the plunger if the pump cavity liquid pressure information matches the phase information of the plunger; and generating an abnormal detection result of the fracturing pump if the liquid pressure information of the fracturing pump does not meet a preset pressure threshold.

In some implementations, the determining liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the phase information of the plunger includes: if the phase information of the plunger is first phase information of the plunger, determining first liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the first phase information of the plunger; and if the phase information of the plunger is second phase information of the plunger, determining second liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the second phase information of the plunger.

In some implementations, after the generating an abnormal detection result of the fracturing pump, the method further includes: triggering an alarm feedback module based on the abnormal detection result to output alarm information; and the generating an abnormal detection result of the fracturing pump if the liquid pressure information of the fracturing pump does not meet a preset pressure threshold includes: if the first liquid pressure information does not meet a preset first pressure information threshold, generating a first detection result of the fracturing pump being abnormal based on the first liquid pressure information; and if the second liquid pressure information does not meet a preset second pressure information threshold, generating a second detection result of the fracturing pump being abnormal based on the second liquid pressure information.

According to a second aspect, the present disclosure provides a fracturing pump detection system, including: a pull rod stress detection module, configured to detect stress information of a pull rod of a fracturing pump through a sensor at a power end of the fracturing pump; a pump cavity liquid pressure information determining module, configured to determine pump cavity liquid pressure information of the fracturing pump according to the stress information of the pull rod; and a detection result determining module, configured to determine a detection result of the fracturing pump according to the pump cavity liquid pressure information and phase information of a plunger corresponding to the stress information of the pull rod.

In some example implementations in the present disclosure, according to the various aspects above, stress information of a pull rod of a fracturing pump is detected through a sensor at a power end of the fracturing pump; pump cavity liquid pressure information of the fracturing pump is determined according to the stress information of the pull rod; and a detection result of the fracturing pump is determined according to the pump cavity liquid pressure information and phase information of a plunger corresponding to the stress information of the pull rod. A process of intermediate filtering and algorithm feature recognition of a conventional vibration sensor is canceled. A problem that in an existing fracturing pump detection method, because a conventional vibration accelerator is used to acquire a signal, intermediate filtering and algorithm feature recognition need to be performed, and as a result data analysis steps are complex is resolved. In addition, an impact of the replacement of a wear part at a hydraulic end on the sensor is avoided, and detection accuracy is improved.

According to a third aspect of this disclosure, a fluid leakage detection method and a fracturing device, to resolve a problem that valve leakage is not detected in time by the current leakage detection means and other problems is provided. The method may be applied to a hydraulic end of a fracturing device, where the hydraulic end includes a valve assembly, and the valve assembly includes an upper valve and a lower valve, and the detection method may include: collecting a change parameter of a fluid and/or a structure in the hydraulic end, and obtaining a corresponding change parameter time domain curve; comparing the change parameter time domain curve with a preset change parameter time domain curve; and determining a leakage status of the upper valve and/or the lower valve according to a phase change difference between the change parameter time domain curve and the preset change parameter time domain curve.

According to a fourth aspect of this disclosure, a fracturing device is provided, The fracturing device may include: a hydraulic end, a first detection element and/or a second detection element, and a control element, where the hydraulic end includes a valve assembly, the valve assembly includes an upper valve and a lower valve, the first detection element is configured to collect a change parameter of a fluid in the hydraulic end, and the second detection element is configured to collect a change parameter of a structure in the hydraulic end. The control element may be configured to: perform control to collect the change parameter of the fluid and/or the structure in the hydraulic end, and obtain a corresponding change parameter time domain curve; compare the change parameter time domain curve with a preset change parameter time domain curve; and determine a leakage status of the upper valve and/or the lower valve according to a phase change difference between the change parameter time domain curve and the preset change parameter time domain curve.

In the fourth and fifth aspects above, by collecting the change parameter of the fluid and/or the change parameter of the structure in the hydraulic end, the corresponding change parameter time domain curve may be obtained, and compared with the preset change parameter time domain curve, to the find the phase change difference, thereby determining a leakage position of the hydraulic end, to help an operator make repair or replacement in time. Therefore, through the detection method in the embodiments of this application, a failed status of a valve can be identified in advance, so that a component such as the valve assembly can be repaired or replaced in time before severe damage occur, the whole robustness of the hydraulic end can be ensured, its service life can be prolonged, and maintenance costs of the valve assembly can be further reduced to some extent.

According to a fifth aspect, the present disclosure further provides a fracturing pump detection device, including a processor, a communication interface, a memory, and a communication bus, where the processor, the communication interface, and the memory communicate with each other through the communication bus; the memory is configured to store a computer program; and the processor is configured to implement, when executing the program stored in the memory, the fracturing pump detection method according to the present disclosure.

According to a sixth aspect, the present disclosure provides a computer-readable storage medium, having a computer program stored therein, where the computer program, when being executed by a processor, implements the fracturing pump detection method according to the present disclosure.

BRIEF DESCRIPTION OF THE DRAWINGS

Accompanying drawings herein are incorporated into the specification and constitute a part of this specification. The drawings show embodiments that conform to the present disclosure, and are used for describing underlying principles of the present disclosure together with this specification.

To describe the technical solutions in the embodiments of the present disclosure or in existing technologies more clearly, the accompanying drawings for describing the embodiments or existing technologies are briefly described below. The embodiments and drawings below are merely examples. A person of ordinary skill in the art may derive other drawings from these accompanying drawings without creative efforts.

FIG. 1 is an example schematic flowchart of a fracturing pump operation detection method according to an example embodiment of the present disclosure;

FIG. 2 is an example schematic structural diagram of a fracturing pump according to an example embodiment of the present disclosure;

FIG. 3 is an example schematic flowchart of steps of a fracturing pump operation detection method according to an example embodiment of the present disclosure;

FIG. 4 is a schematic diagram of a fracturing pump operation detection system according to an example embodiment of the present disclosure;

FIG. 5 is an example structural block diagram of a fracturing pump operation detection system according to an example embodiment of the present disclosure; and

FIG. 6 is an example schematic structural diagram of a fracturing pump operation detection device according to an example embodiment of the present disclosure.

FIG. 7 is a schematic structural diagram of a hydraulic end of a fracturing device according to an embodiment of this application;

FIG. 8 is a schematic diagram of comparison between fluid pressure time domain curves in a high-pressure region (for example, in a valve box) when leakage occurs in an upper valve according to an embodiment of this application;

FIG. 9 is a schematic diagram of comparison between fluid pressure time domain curves in a high-pressure region (for example, in a valve box) when leakage occurs in a lower valve according to an embodiment of this application;

FIG. 10 is a schematic diagram of comparison between fluid pressure time domain curves in a high-pressure region (for example, in a valve box) when leakage occurs in both an upper valve and a lower valve according to an embodiment of this application;

FIG. 11 is a schematic diagram of actually measured values of fluid pressure in a high-pressure region (for example, in a valve box) when leakage occurs in an upper valve according to an embodiment of this application;

FIG. 12 is a schematic diagram of actually measured values of fluid pressure in a high-pressure region (for example, in a valve box) when leakage occurs in a lower valve according to an embodiment of this application;

FIG. 13 is a schematic diagram of actually measured values of fluid pressure in a high-pressure region (for example, in a valve box) when leakage occurs in both an upper valve and a lower valve according to an embodiment of this application;

FIG. 14 is a schematic diagram of comparison between fluid pressure time domain curves in a low-pressure region (for example, at an entrance of a lower valve) when leakage occurs in an upper valve according to an embodiment of this application;

FIG. 15 is a schematic diagram of comparison between fluid pressure time domain curves in a low-pressure region (for example, at an entrance of a lower valve) when leakage occurs in the lower valve according to an embodiment of this application;

FIG. 16 is a schematic diagram of comparison between fluid pressure time domain curves in a low-pressure region (for example, at an entrance of a lower valve) when leakage occurs in both an upper valve and the lower valve according to an embodiment of this application;

FIG. 17 is a schematic diagram of comparison between fluid flow time domain curves at an entrance of a lower valve when leakage occurs in an upper valve according to an embodiment of this application;

FIG. 18 is a schematic diagram of comparison between fluid flow time domain curves at an entrance of a lower valve when leakage occurs in the lower valve according to an embodiment of this application; and

FIG. 19 is a schematic diagram of comparison between fluid flow time domain curves at an entrance of a lower valve when leakage occurs in both an upper valve and the lower valve according to an embodiment of this application.

• • 1—pull rod
  • 2—tension or strain sensor
  • 3—plunger
  • 4—liquid discharge pressure sensor
  • 5—liquid suction pressure sensor
  • 200—Fracturing pump
  • 7-100—valve assembly;
  • 7-110—upper valve;
  • 7-120—lower valve;
  • 7-200—valve box;
  • 7-300—plunger;
  • 7-400—end cover;
  • 7-500—liquid feeding pipeline;
  • 7-610—pressure sensor;
  • 7-620—flow sensor; and
  • 7-630—stress strain sensor.

DETAILED DESCRIPTION

To make the objectives, technical solutions, and advantages of the embodiments of the present disclosure clearer, the following describes the technical solutions in the embodiments of the present disclosure with reference to the accompanying drawings in the embodiments of the present disclosure. Apparently, the described embodiments are merely some embodiments of the present disclosure rather than all of the embodiments. All other embodiments obtained by a person of ordinary skill in the art based on the embodiments of the present disclosure without creative efforts shall fall within the protection scope of the present disclosure.

During implementation, a detection sensor may be mainly mounted at a hydraulic end of a fracturing pump. For example, at least one sensor may be mounted on an upper surface or a lower surface of the hydraulic end of the fracturing pump. However, high-pressure and low-pressure valves inside the hydraulic end of the fracturing pump are members subject to wear, and may often need to be replaced. During replacement of these components, plugs at upper and lower ends of the hydraulic end of the fracturing pump need to be removed. In a process of removing the plugs, because the sensor mounted at the hydraulic end is prone to being knocked on and as a result is prone to damage, maintenance or repair or replacement costs of the sensor may be increased or elevated.

The example embodiments of the present disclosure below are to provide a fracturing pump operation detection method (for detecting manifestation of operational issues of the fracturing pump). A sensor may be mounted at a power end of the fracturing pump. Stress information of a pull rod of the fracturing pump may be detected, to determine a detection result of the fracturing pump according to the stress information of the pull rod. The real-time detection of operation in the fracturing pump may be implemented. An indirect process of intermediate filtering and algorithmic feature recognition in a conventional vibration sensor is avoided. As such, the risk of damages in the hydraulic end due to untimely detection of operation faults and may be reduced, and operation fault detection accuracy is further improved.

FIG. 1 is a schematic flowchart of a fracturing pump detection method according to the present disclosure. As shown in FIG. 1, the fracturing pump detection method provided in the present disclosure may include the following steps.

Step 110: Detect stress information of a pull rod of a fracturing pump through a sensor at a power end of the fracturing pump.

Step 120: Determine pump cavity liquid pressure information of the fracturing pump according to the stress information of the pull rod.

Step 130: Determine a detection result of the fracturing pump according to the pump cavity liquid pressure information and phase information of a plunger corresponding to the stress information of the pull rod.

In some example implementations, the power end of the fracturing pump may be an end of the pull rods of the fracturing pump connected to the plunger. The sensor may be mounted at one of more of the pull rods of the fracturing pump. For example, a diaphragm tension or strain sensor may be mounted. This is not limited in the present disclosure. When performing fracturing operation, the fracturing pump may determine pulling force data or pushing force data on the pull rods of the fracturing pump according to information fed back by the diaphragm tension or strain sensor, and may use the pulling force data or pushing force data as the stress information of the pull rods of the fracturing pump.

In some implementations, a plurality of tension or strain sensors may be respectively mounted for or on a plurality of pull rods of the fracturing pump. Each tension or strain sensor may be mounted at an end of a pull rod corresponding to each pump cavity of the fracturing pump close to the plunger. In this way, when the fracturing pump performs fracturing operation, the tension or strain sensors may acquire deformation data of the pull rods, so that the deformation data of the pull rods may be converted into tension or strain information. A pushing force or a pulling force on a pull rod may be obtained according to the tension or strain information. For example, a pushing force on the pull rod performing an extension movement or a pulling force on the pull rod performing a retraction movement may be obtained. Because the sensors are not installed on the hydraulic end, damages to the sensors and reinstallation of the sensors may be avoided in a process of disassembling the hydraulic end in a service process to repair a damaged sealing member at a hydraulic end of the fracturing pump. In other words, damage of the sensor caused by impacts on the sensor during such disassembly process may be avoided. In addition, repositioning inaccuracy after such disassembly and then assembly is reduced because the sensors need not be disassembled from the rods.

In some example implementations, the tension or strain sensor monitors status data of the pull rod, and obtained tension/strain information is more accurate. Tension or strain information is more stable and is insusceptible to impacts of other members, vibration, temperature, and the like, and the accuracy of signal capture is higher.

In some example implementations, after the stress information of the pull rods is determined, the pump cavity liquid pressure information of the fracturing pump may be determined according to the stress information of the pull rod. Specifically, the pulling force or the pushing force on the pull rod may be determined according to the stress information of the pull rods, and a cross-sectional area of the plunger of the fracturing pump and the pulling force or the pushing force on the pull rod are used to calculate and obtain the pump cavity liquid pressure information corresponding to the pull rods of the fracturing pump.

During an example processing, a unique IP address may be set aside for each of the tension or strain sensor. For example, a group of tension or strain sensors may be mounted at each of a horizontal position and a vertical position of the pull rods, and unique IP addresses may be respectively set for the two groups of tension or strain sensors. In subsequent processing, a sensor to which acquired tension or strain information belongs may be recognized, and a pull rod at which the sensor is mounted and a mounting position of the sensor can be recognized, so that the obtained pump cavity liquid pressure information of the fracturing pump is more accurate and informational. For example, each of the sensors may be mounted on a particular rod and at a particular position on that rod. Because each sensor may be attributed with a unique IP address for communicating the detected information, a controller of the plunger pump would recognize the detected information as for the rod and position corresponding to the unique IP address. In some implementations, the sensors may be grouped with each group being associated with a unique IP address.

It can be seen that, the tension/strain information acquired by the tension or strain sensors in the embodiments of the present disclosure may be directly converted into the pump cavity liquid pressure information, and special algorithmic recognition and filtering are not required, so that data analysis steps are simplified, signal processing efficiency is improved, and a feedback of a fault or a potential fault in the fracturing pump (e.g., the hydraulic end of the fracturing pump) is more timely.

In some implementations, the phase information of the plunger of the fracturing pump may be determined according to the extension movement or the retraction movement of the pull rods, so that the detection result of the fracturing pump may be determined according to the phase information of the plungers and the pump cavity liquid pressure information. In some example implementations, it may be determined, by recognizing the tension or strain information of the pull rods, whether the pull rods are currently performing the extension movement or the retraction movement, so that the phase information of the plungers of the fracturing pump can be obtained. If a pull rod performs the extension movement currently, liquid discharge liquid pressure information of the fracturing pump may be determined according to the phase information of the plunger and the pump cavity liquid pressure information. If a pull rod performs the retraction movement currently, liquid suction liquid pressure information of the fracturing pump may be determined according to the phase information of the plunger and the pump cavity liquid pressure information. In this way, the detection results of the fracturing pump may be respectively determined according to the liquid discharge liquid pressure information of the fracturing pump and the liquid suction liquid pressure information of the fracturing pump.

In some example implementations, in a schematic structural diagram of a fracturing pump 200 shown in FIG. 2, a pull rod 1 may be connected to a plunger 3, and a tension or strain sensor 2 may be mounted at an end of a pull rod corresponding to a pump cavity of the fracturing pump close to a plunger. In some implementations, a mounting direction of the tension or strain sensor may be an axial direction of the pull rod. A group of sensors may be mounted in each of a horizontal direction and a vertical direction of the pull rod, to respectively acquire tension or strain information of the pull rod in the horizontal direction and the vertical direction, and the stress information of the pull rod may be determined according to the acquired tension or strain information. The pump cavity liquid pressure information of the fracturing pump may correspondingly be determined according to the stress information of the pull rod. For example, when the pull rod is performing the extension movement (motion to the right in FIG. 2), the pushing force on the pull rod may be determined according to the tension or strain information, and the pushing force on the pull rod may then be used as the stress information of the pull rod to determine the liquid discharge liquid pressure information of the fracturing pump according to the stress information of the pull rod. When the pull rod is performing the retraction movement (motion to the left in FIG. 2), the pulling force on the pull rod may be determined according to the tension or strain information, and the pulling force on the pull rod may be used as the stress information of the pull rod, to determine the liquid suction liquid pressure information of the fracturing pump according to the stress information of the pull rod. In addition, at least one liquid discharge pressure sensor 4 may further be mounted at a high-pressure outlet end of the fracturing pump, to acquire pressure data at the high-pressure outlet end of the fracturing pump. At least one liquid suction pressure sensor 5 may further be mounted at a low-pressure outlet end of the fracturing pump, to acquire pressure data at the low-pressure outlet end of the fracturing pump. Further details of an example fracturing pump such as a plunger pump are shown in FIG. 7 and corresponding description below.

In some implementations, after the liquid discharge liquid pressure information of the fracturing pump is determined, the liquid discharge liquid pressure information of the fracturing pump may be compared with the acquired pressure data at the high-pressure outlet end of the fracturing pump, so that the detection result of the fracturing pump (indicating operation status of the pump in discharging phase) can be determined. Likewise, after the liquid suction liquid pressure information of the fracturing pump is determined, the liquid suction liquid pressure information of the fracturing pump may be compared with the acquired pressure data at the low-pressure outlet end of the fracturing pump, so that the detection result of the fracturing pump (indicating operation status of the pump in suction phase) can be determined.

In some example implementations, during reciprocal movements of extension and retraction of the pull rod, when the pull rod performs the extension movement, the pull rod applies a pushing force to the plunger. In this case, a volume inside the fracturing pump is reduced, and the pump cavity of the fracturing pump discharges a liquid. When the pull rod performs the retraction movement, the pull rod applies a pulling force to the plunger. In this case, the volume inside the fracturing pump is increased, and the pump cavity of the fracturing pump sucks a liquid. Based on the foregoing principle, after the tension or strain information corresponding to the tension or strain sensor of a pull rod is acquired, a tension or strain direction corresponding to the tension or strain information may be determined based on the tension or strain information, so that it can be determined whether the pull rod is in an extended state or in a retracted state, and the phase information of the plunger can be determined according to the status data of the pull rod being extended or retracted. The pump cavity of the fracturing pump may encounter a special failure. For example, a form of the special failure may be that the pump cavity of the fracturing pump encounters only a liquid discharge abnormality or encounters only a liquid suction abnormality. In the case of the special failure, because abnormality data of the liquid discharge abnormality or liquid suction abnormality in one suction-discharge cycle is not obvious, the liquid discharge abnormality or liquid suction abnormality may fail to be detected immediately if the phase of the operation were not detected. By also detecting the phase, the special failure can be accurately determined in a timely manner, so that the accuracy of monitoring the fracturing pump is greatly enhanced.

In some example implementations, in the present disclosure, stress information of a pull rod of a fracturing pump is detected through a sensor at a power end of the fracturing pump; pump cavity liquid pressure information of the fracturing pump is determined according to the stress information of the pull rod; and a detection result of the fracturing pump is determined according to the pump cavity liquid pressure information and phase information of a plunger corresponding to the stress information of the pull rod. The detection and derivation are direct. A process of intermediate filtering and algorithmic feature recognition in a conventional vibration sensor is avoided. The problems associated with such conventional method are also avoided. For example, in an existing fracturing pump detection method, because a conventional vibration accelerator is used to acquire a signal, intermediate filtering and algorithm feature recognition need to be performed, and as a result data analysis steps are complex. The example implementations above would avoid such complexity. The existing method may be inaccurate and the detection may be untimely, leading to continued pump operation in the presence of undetected hydraulic end failure, leading to damages, wearing, and frequent need for replacement of worn parts. The example implementations above would help alleviate these issues as well.

FIG. 3 is a schematic flowchart of steps of a fracturing pump detection method according to an example embodiment of the present disclosure. The fracturing pump detection method may include the following steps:

Step 310: Detect stress information of one or more pull rods of a fracturing pump through one or more sensors at a power end of the fracturing pump.

Step 320: Obtain piston cross-sectional area information of the fracturing pump for the stress information of the pull rods.

Step 330: Perform calculation based on the piston cross-sectional area information and the stress information of the pull rods, to obtain pump cavity liquid pressure information of the fracturing pump.

Step 340: Determine phase information of a plunger corresponding to the stress information of the pull rods.

Step 350: Detect whether the pump cavity liquid pressure information matches the phase information of the plungers.

Step 360: Determine liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the phase information of the plungers if the pump cavity liquid pressure information matches the phase information of the plungers.

Step 370: Determine an abnormal detection result of the fracturing pump if the liquid pressure information of the fracturing pump does not meet one or more preset pressure threshold values.

Step 380: Trigger an alarm feedback module based on the abnormal detection result to output alarm information.

In some implementations, the sensor at the power end may include one or more tension sensors mounted at the pull rods of the fracturing pump, and detecting stress information of the pull rods of a fracturing pump through one or more sensors at a power end of the fracturing pump may include the following substeps.

Substep 3101: Obtain end tension information of the pull rods detected by the tension sensors.

Substep 3102: Determine the stress information of the pull rods based on the end tension information of the pull rods and preset end cross-sectional area information of the pull rods corresponding to the fracturing pump.

In some example implementations, if a sensor mounted at a pull rod is a tension sensor, when the fracturing pump performs fracturing operation, deformation data of the pull rod may be obtained, and the deformation data may be converted into the end tension information of the pull rod. An end cross-sectional area of the pull rod of the fracturing pump is fixed. Therefore, the end cross-sectional area of the pull rod may be used as the preset end cross-sectional area information of the pull rod. Subsequently, the tension information of the pull rod and the preset end cross-sectional area information of the pull rod corresponding to the fracturing pump may be calculated, so that the stress information of the pull rod can be determined.

In some example implementations, an end tension of a pull rod corresponding to the end tension information of the pull rod may be σ, and the end cross-sectional area of the pull rod corresponding to the preset end cross-sectional area information of the pull rod may be A1. Through the formula: F=σ*A1, a pushing force or pulling force F on the pull rod corresponding to the stress information of the pull rod may be obtained.

In some example implementations, a sensor at the power end may include a strain sensor mounted at a pull rod of the fracturing pump, and the detecting stress information of the pull rod of the fracturing pump through the sensor at a power end of the fracturing pump may include the following substeps.

Substep 3103: Obtain end strain information of the pull rod detected by the strain sensor.

Substep 3104: Determine the stress information of the pull rod based on the end strain information of the pull rod, preset elastic modulus information of a material of the pull rod corresponding to the fracturing pump, and the preset end cross-sectional area information of the pull rod corresponding to the fracturing pump.

In some example implementations, if the sensor mounted at a pull rod is a strain sensor, when the fracturing pump performs fracturing operation, deformation data of the pull rod may be obtained, and the deformation data may be converted into the end strain information of the pull rod. An elastic modulus of the material of the pull rod of the fracturing pump and an end cross-sectional area of the pull rod of the fracturing pump may both be fixed. Therefore, the elastic modulus of the material of the pull rod may be used as the preset elastic modulus information of the material of the pull rod, and the end cross-sectional area of the pull rod may be used as the preset end cross-sectional area information of the pull rod. Subsequently, the strain information of the pull rod, the preset elastic modulus information of the material of the pull rod corresponding to the fracturing pump, and the preset end cross-sectional area information of the pull rod corresponding to the fracturing pump may be calculated, so that the stress information of the pull rod can be determined.

In some example implementations, an end strain of a pull rod corresponding to the end strain information of the pull rod may be ε, the elastic modulus of the material of the pull rod corresponding to the preset elastic modulus information of the material of the pull rod may be E, and the end cross-sectional area of the pull rod corresponding to the preset end cross-sectional area information of the pull rod may be A1. Through the formula: F=ε*E*A1, a pushing force or pulling force F on the pull rod corresponding to the stress information of the pull rod may be obtained.

In some example implementations, the piston cross-sectional area information of the fracturing pump may be the cross-sectional area of the plunger of the fracturing pump. After the pulling force or the pushing force on the pull rod is determined, the pump cavity liquid pressure information of the fracturing pump may be obtained based on the cross-sectional area of the plunger of the fracturing pump and the pulling force or the pushing force on the pull rod.

In some example implementations, the cross-sectional area of the plunger of the fracturing pump may be A2, and the pulling force or the pushing force on the pull rod may be F. Through the formula: P=F/A2, the pump cavity liquid pressure information P of the fracturing pump may be obtained.

In some example implementations, after the end tension or strain information of the pull rod is determined, tension or strain information may be recognized, a tension or strain direction is determined, and a current movement status of the pull rod may be further determined based on the tension or strain direction. For example, it may be determined whether the pull rod performs an extension movement or a retraction movement. In this way, it may be determined, based on the current movement status of the pull rod, whether a force on the pull rod is a pushing force or a pulling force.

In some example implementations, the current movement status of the pull rod is the extension movement, and it may be determined that the force on the pull rod is a pushing force. In another example, the current movement status of the pull rod is the retraction movement, and it may be determined that the force on the pull rod is a pulling force. In subsequent processing, the phase information of the plunger may be determined according to the extension movement or the retraction movement of the pull rod, the fracturing pump, so that the detection result of the fracturing pump may be determined according to the phase information of the plunger and the pump cavity liquid pressure information of the fracturing pump.

In some example implementations, after the end tension or strain information of the pull rod is acquired, the pulling force or the pushing force on the pull rod can be quickly obtained based on the tension or strain information, so that the pump cavity liquid pressure information of the fracturing pump may be obtained based on the pulling force or the pushing force on the pull rod in combination with the preset cross-sectional area of the plunger of the fracturing pump. Special algorithmic recognition or data filtering is not required, and complex data analysis and calculation is also not required, so that data processing efficiency is improved, and a feedback can be made in a timely manner when the fracturing pump encounters a fault, thereby enabling real-time detection of the fracturing pump and avoiding a larger loss.

In some example implementations, the phase information of the plunger may be status data of the pull rod being extended or retracted. If the force on the pull rod corresponding to the stress information of the pull rod is a pulling force, it may be determined that the pull rod performs the retraction movement, and the phase information of the plunger when the pull rod performs the retraction movement may be obtained. If the force on the pull rod corresponding to the stress information of the pull rod is a pushing force, it may be determined that the pull rod performs the extension movement, and the phase information of the plunger when the pull rod performs the extension movement may be obtained.

In some example implementations, status data when the pull rod is completely extended in the extension movement or status data when the pull rod is completely retracted in the retraction movement may be used as the phase information of the plunger. Specifically, corresponding tension or strain information when the pull rod performs the extension movement may be defined to be negative, and corresponding tension or strain information when the pull rod performs the retraction movement may be defined to be positive. After the end tension or strain information of the pull rod is acquired, it may be determined, according to a positive signal or a negative signal included in the tension or strain information, whether the pull rod is performing the extension movement or the retraction movement. If the acquired tension or strain information includes a positive signal, it may be determined that the pull rod performs the retraction movement. If the acquired tension or strain information includes a negative signal, it may be determined that the pull rod performs the extension movement. If the acquired tension or strain information changes from a positive signal into a negative signal, it may be determined that the pull rod has been retracted to a maximum position and is about to extend. In this case, it may be determined that the pull rod has been completely retracted, and the status data when the pull rod is completely retracted may be used as the phase information of the plunger. When the acquired tension or strain information changes from a negative signal into a positive signal, it may be determined that the pull rod has been extended to a maximum position and is about to retract. In this case, it may be determined that the pull rod has been completely extended, and the status data when the pull rod is completely extended may be used as the phase information of the plunger.

In some example implementations, the pump cavity liquid pressure information may be matched against the phase information of the plunger. If the movement status of the pull rod corresponding to the pump cavity liquid pressure information is extended and the movement status of the pull rod corresponding to the phase information of the plunger is also extended, it may be determined that the pump cavity liquid pressure information matches the phase information of the plunger. If the movement status of the pull rod corresponding to the pump cavity liquid pressure information is retracted and the movement status of the pull rod corresponding to the phase information of the plunger is also retracted, it may be determined that the pump cavity liquid pressure information matches the phase information of the plunger.

In addition, it may further be determined whether the movement status of the pull rod corresponding to the phase information of the plunger is completely extended or completely retracted. If the movement status of the pull rod corresponding to the pump cavity liquid pressure information is completely extended and the movement status of the pull rod corresponding to the phase information of the plunger is also completely extended, it may be determined that the pump cavity liquid pressure information matches the phase information of the plunger. If the movement status of the pull rod corresponding to the pump cavity liquid pressure information is completely retracted and the movement status of the pull rod corresponding to the phase information of the plunger is also completely retracted, it may be determined that the pump cavity liquid pressure information matches the phase information of the plunger.

In some example implementations, the liquid pressure information of the fracturing pump may include liquid discharge liquid pressure information of the fracturing pump and liquid suction liquid pressure information of the fracturing pump. If the pump cavity liquid pressure information matches the phase information of the plunger and the movement status of the pull rod corresponding to the pump cavity liquid pressure information and the phase information of the plunger is extended, it may be determined that the liquid pressure information of the fracturing pump is the liquid discharge liquid pressure information of the fracturing pump. If the pump cavity liquid pressure information matches the phase information of the plunger and the movement status of the pull rod corresponding to the pump cavity liquid pressure information and the phase information of the plunger is retracted, it may be determined that the liquid pressure information of the fracturing pump is the liquid suction liquid pressure information of the fracturing pump.

In some implementations, determining the liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the phase information of the plunger may include the following steps.

Substep 3601: If the phase information of the plunger is first phase information of the plunger, determine first liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the first phase information of the plunger.

Substep 3602: If the phase information of the plunger is second phase information of the plunger, determine second liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the second phase information of the plunger.

In some implementations, the first phase information of the plunger may be the status data when the pull rod is completely extended, and the second phase information of the plunger may be the status data when the pull rod is completely retracted. The first liquid pressure information may be the liquid discharge liquid pressure information of the fracturing pump as detected, and the second liquid pressure information may be the liquid suction liquid pressure information of the fracturing pump as detected.

In some example implementations, it may be respectively determined whether the liquid suction liquid pressure information of the fracturing pump and the liquid discharge liquid pressure information meet a preset pressure threshold, to determine the detection result of the fracturing pump according to the liquid suction liquid pressure information and the liquid discharge liquid pressure information.

In some example implementations, a liquid suction pressure sensor may be mounted near a low-pressure liquid inlet of the fracturing pump, to acquire pressure information at the liquid inlet of the fracturing pump, and a liquid discharge pressure sensor may be mounted near a high-pressure liquid outlet of the fracturing pump, to acquire pressure information at the liquid outlet of the fracturing pump. Subsequently, the liquid suction liquid pressure information of the fracturing pump as detected may be compared with the pressure information at the liquid inlet of the fracturing pump, to obtain liquid suction pressure difference information; and the liquid discharge liquid pressure information of the fracturing pump as detected may be compared with the pressure information at the liquid outlet of the fracturing pump, to obtain liquid discharge pressure difference information. The liquid suction pressure difference information or the liquid discharge pressure difference information may be compared with the preset pressure threshold (or pressure difference threshold), to determine whether the liquid suction pressure difference information or the liquid discharge pressure difference information meets the preset pressure difference threshold. In a case that the liquid suction pressure difference information or the liquid discharge pressure difference information does not meet the preset pressure difference threshold, the abnormal detection result of the fracturing pump is indicated or determined. Specifically, two pressure difference thresholds may be preset. For example, the preset two pressure thresholds may be a high pressure threshold and the low pressure threshold. The liquid suction pressure difference information may be compared with the preset high pressure difference threshold. If the liquid suction pressure difference information is higher than the preset high pressure difference threshold, it may be determined that the fracturing pump encounters an abnormality, and the abnormality may be that a low-pressure sealing failure has occurred inside the hydraulic end of the fracturing pump. Likewise, the liquid discharge pressure difference information may be compared with the preset low pressure difference threshold. If liquid discharge pressure difference information is lower than the preset low pressure difference threshold, it may be determined that the fracturing pump encounters an abnormality, and the abnormality may be that a high-pressure sealing failure has occurred inside the hydraulic end of the fracturing pump. The liquid suction pressure difference information or the liquid discharge pressure difference information is compared with the preset pressure difference threshold. A degree of a sealing failure inside the fracturing pump can be intuitively learned according to a comparison result, so that a monitoring result is more accurate.

In some implementations, FIG. 4 is a schematic diagram of a fracturing pump operation detection system 500 according to the present disclosure. The system may include an independent sensor and a remote monitoring platform. The independent sensor may include a signal acquisition module, a power supply module, and a signal transmission module. The remote monitoring platform may include a signal receiving module and an operation panel, and the operation panel may include a data processing module, a threshold setting module, and the alarm feedback module. In some example implementations, the signal acquisition module may include a diaphragm tension or strain sensor, the liquid suction pressure sensor, and/or the liquid discharge pressure sensor. The power supply module may be an independent storage battery, or the like. This is not limited in this example. The power supply module may supply electrical energy to the signal acquisition module and the signal transmission module, to enable the signal acquisition module and the signal transmission module to enter an operation status according to the electrical energy supplied by the power supply module. In some example implementations, the tension or strain sensor may be mounted in an axial direction of the pull rod. For example, a group of sensors may be mounted in each of a horizontal direction and a vertical direction of the pull rods, the liquid suction pressure sensor may be mounted near the low-pressure liquid inlet of the fracturing pump, and the liquid discharge pressure sensor may further be mounted at the high-pressure outlet end of the fracturing pump. This is not limited in the present disclosure. A group of tension or strain sensors may be mounted in each of the horizontal direction and the vertical direction of the pull rods, so that the signal acquisition module may respectively acquire tension or strain information in a horizontal position and a vertical position of the pull rods, and send the acquired tension or strain information to the signal transmission module, to trigger the signal transmission module to send the tension or strain information the signal receiving module of the remote monitoring platform. For example, the signal transmission module may be remotely and wirelessly connected to the signal receiving module of the remote monitoring platform, so that the signal receiving module may receive the tension or strain information sent by the signal transmission module. Subsequently, the signal receiving module may output the tension or strain information to the data processing module, so that the data processing module may determine the liquid pressure information of the fracturing pump according to the tension or strain information, and recognize, according to the tension or strain information, whether the pull rods perform the extension movement or the retraction movement, thereby obtaining the phase information of the plunger of the fracturing pump. In some implementations, the data processing module may further match the pump cavity liquid pressure information of the fracturing pump against corresponding phase information of the plunger, to obtain the liquid suction liquid pressure information of the fracturing pump or the liquid discharge liquid pressure information.

In addition, the signal acquisition module may further send the pressure information at the liquid inlet of the fracturing pump acquired by the liquid suction pressure sensor and the pressure information at the liquid outlet of the fracturing pump acquired by the liquid discharge pressure sensor to the data processing module through the signal transmission module and the signal receiving module. The data processing module may compare the liquid suction liquid pressure information of the fracturing pump with the pressure information at the liquid inlet of the fracturing pump, to obtain the liquid suction pressure difference information; and may compare the liquid discharge liquid pressure information of the fracturing pump with the pressure information at the liquid outlet of the fracturing pump, to obtain the liquid discharge pressure difference information. Subsequently, the data processing module may obtain a pressure difference threshold set by the threshold setting module. If the liquid discharge pressure difference information is lower than the pressure difference threshold or liquid suction pressure difference information is higher than the pressure difference threshold, the data processing module may determine that the fracturing pump encounters an abnormality, and generate the abnormal detection result of the fracturing pump. In subsequent processing, the data processing module may trigger the alarm feedback module according to the abnormal detection result to send out alarm information. For example, the data processing module may trigger the alarm feedback module to send out a sound and light alarm and the like. This is not limited in this example. An alarm is sent out to an operator to prompt the operator. The operator may determine abnormality information of the fracturing pump through the operation panel, for example, the operator may determine high-pressure or low-pressure leakage or the like of the fracturing pump. This is not limited in this example. In addition, the operator may further implement the setting of the pressure difference threshold in the threshold setting module through the operation panel, for example, may adjust the value, and the like of the pressure difference threshold.

In some example scenarios, when a failure occurs inside the hydraulic end of the fracturing pump, e.g., micro leakage, fracture, or the like in valve box or at the packing sealing, a liquid in the pump cavity of the fracturing pump may flow out from the leakage or fracture, leading to a liquid pressure abnormality in the pump cavity during both the extension phase and retraction phase of the plungers. In this case, the plunger feeds back the abnormality to the pull rods. A specific manifestation is that the pushing force of the pull rod may be reduced, and a tension or strain degree in the pull rods may decrease. Corresponding changes also occur in the tension or strain information fed back by the tension or strain sensors. Therefore, it may be quickly analyzed through the acquired end tension or strain information of the pull rods in combination with the phase information of the plungers whether a failure has occurred at high-pressure sealing or low-pressure sealing, so that the detection of the fracturing pump faults is more timely and accurate.

In some example scenarios, a low-pressure sealing failure may occur at the hydraulic end of the fracturing pump. Under such a failure, when the pull rod performs the retraction movement, a liquid enters from the low pressure side of the hydraulic end of the fracturing pump and the valve box may not leak under the liquid-drawing operation, and the phase information and the force information as detected may show normal operation of the plunger in retraction movement. When the pull rod performs the extension movement, however, the fracturing liquid discharges from the high pressure side of the hydraulic end of the fracturing pump. In this case, because leakage would occur at low pressure sealing, a high normal pressure value cannot be kept at the hydraulic end of the fracturing pump for discharging. Thus the pushing force and the detected tension values on the pull rods is reduced would be lower than normal, allowing for detection of the low pressure sealing failure of the hydraulic end of the fracturing pump.

In some example scenarios, a failure occurs at the high-pressure sealing of the hydraulic end of the fracturing pump. Under such failure, when the pull rods perform the extension movement, a liquid discharges from a liquid outlet end of the hydraulic end of the fracturing pump. The liquid discharge end of the fracturing pump is connected in series to another operation liquid cavity, so that pressures at liquid discharge ends would appear being maintained. Therefore, in an extension phase of the pull rod, the tension information detected by the tension sensor would be normal. When the pull rod performs the retraction movement, a liquid is sucked from the hydraulic end of the fracturing pump. In this case, because leakage occurs at high pressure sealing, a high pressure outside the liquid outlet end of the fracturing pump is transferred into the pump cavity of the fracturing pump through the leakage. As a result, a pressure in the pump cavity would be higher than a normal value for the retraction stage. The pull rods may thus be subject to an abnormal pushing force from the hydraulic end side. When the pull rods are completely retracted, a required pulling force as detected decreases. In this case, the tension information of the pull rods detected by the tension sensor also be abnormally high and then decrease, allowing for detection of the leakage in the sealing on the high pressure side of the hydraulic end of the fracturing pump.

In the above example implementations, the step of generating an abnormal detection result of the fracturing pump if the liquid pressure information of the fracturing pump does not meet a preset pressure threshold (or preset pressure difference threshold above) may include: if the first liquid pressure information does not meet a preset first pressure information threshold, generating a first detection result of the fracturing pump being abnormal based on the first liquid pressure information; and if the second liquid pressure information does not meet a preset second pressure information threshold, generating a second detection result of the fracturing pump being abnormal based on the second liquid pressure information. The preset pressure thresholds may be implemented as the preset pressure difference thresholds above.

In some example implementations, after the abnormal detection result of the fracturing pump is determined, the alarm feedback module may be triggered based on the abnormal detection result to send out alarm information. For example, a sound and light alarm may be sent out, to prompt the operator, and the fracturing pump encounters an abnormality. This is not limited in the present disclosure.

In some implementations, the first liquid pressure information may be the liquid suction liquid pressure information, and the first pressure information threshold may be the high pressure difference threshold above. The second liquid pressure information may be the liquid discharge liquid pressure information, and the second pressure information threshold may be the low pressure difference threshold. This is not limited in the present disclosure.

It can be seen that, in the embodiments of the present disclosure, stress information of pull rods of a fracturing pump is detected through a sensor at a power end of the fracturing pump. Piston cross-sectional area information of the fracturing pump is obtained for the stress information of the pull rod. Calculation is performed based on the piston cross-sectional area information and the stress information of the pull rod to obtain pump cavity liquid pressure information of the fracturing pump, to determine phase information of a plunger corresponding to the stress information of the pull rod. It is detected whether the pump cavity liquid pressure information matches the phase information of the plunger, so that when the pump cavity liquid pressure information matches the phase information of the plunger, liquid pressure information of the fracturing pump is determined according to the pump cavity liquid pressure information and the phase information of the plunger. An abnormal detection result of the fracturing pump is determined when the liquid pressure information of the fracturing pump does not meet a preset pressure threshold. An alarm feedback module is triggered based on the abnormal detection result to output alarm information. A process of intermediate filtering and algorithmic feature recognition in a conventional vibration sensor is avoided.

The problems associated with such conventional method are also avoided. For example, in an existing fracturing pump detection method, because a conventional vibration accelerator is used to acquire a signal, intermediate filtering and algorithm feature recognition need to be performed, and as a result data analysis steps are complex. The example implementations above would avoid such complexity. The existing method may be inaccurate and the detection may be untimely, leading to continued pump operation in the presence of undetected hydraulic end failure, leading to damages, wearing, and frequent need for replacement of worn parts. The example implementations above would help alleviate these issues as well.

It is noted that for each of the method embodiments, for ease of description, the method embodiment is described as a series of action combinations, but a person having ordinary skill in the art should understand that the embodiments of the present disclosure is not limited to an order of described actions, because according to the embodiments of the present disclosure, some steps may be performed in another order or at the same time.

As shown in FIG. 5, the present disclosure provides a fracturing pump detection system 500, including: a pull rod stress detection module 510, configured to detect stress information of pull rods of a fracturing pump through a sensor at a power end of the fracturing pump; a pump cavity liquid pressure information determining module 520, configured to determine pump cavity liquid pressure information of the fracturing pump according to the stress information of the pull rods; and a detection result determining module 530, configured to determine a detection result of the fracturing pump according to the pump cavity liquid pressure information and phase information of a plunger corresponding to the stress information of the pull rods.

In some example implementations, the sensors at the power end includes tension sensors mounted at the pull rods of the fracturing pump, and the detecting stress information of pull rods of a fracturing pump through sensors at a power end of the fracturing pump includes: obtaining end tension information of the pull rods detected by the tension sensors; and determining the stress information of the pull rods based on the end tension information of the pull rods and preset end cross-sectional area information of the pull rods corresponding to the fracturing pump.

In some implementations, the sensors at the power end include strain sensors mounted at the pull rods of the fracturing pump, and the detecting stress information of the pull rods of the fracturing pump through sensors at the power end of the fracturing pump includes: obtaining end strain information of the pull rods detected by the strain sensors; and determining the stress information of the pull rods based on the end strain information of the pull rods, preset elastic modulus information of a material of the pull rods corresponding to the fracturing pump, and the preset end cross-sectional area information of the pull rods corresponding to the fracturing pump.

In some implementations, determining pump cavity liquid pressure information of the fracturing pump according to the stress information of the pull rods includes: obtaining piston cross-sectional area information of the fracturing pump for the stress information of the pull rods; and performing calculation based on the piston cross-sectional area information and the stress information of the pull rods, to obtain the pump cavity liquid pressure information of the fracturing pump.

In some implementations, determining a detection result of the fracturing pump according to the pump cavity liquid pressure information and phase information of plungers corresponding to the stress information of the pull rods includes: determining the phase information of the plungers corresponding to the stress information of the pull rods; detecting whether the pump cavity liquid pressure information matches the phase information of the plungers; determining liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the phase information of the plungers if the pump cavity liquid pressure information matches the phase information of the plungers; and generating an abnormal detection result of the fracturing pump if the liquid pressure information of the fracturing pump does not meet a preset pressure threshold.

In some implementations, determining liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the phase information of the plungers includes: if the phase information of the plunger is first phase information of a plunger, determining first liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the first phase information of the plunger; and if the phase information of the plunger is second phase information of the plunger, determining second liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the second phase information of the plunger.

In some implementations, after the generating an abnormal detection result of the fracturing pump, the method further includes: triggering an alarm feedback module based on the abnormal detection result to output alarm information; wherein generating an abnormal detection result of the fracturing pump if the liquid pressure information of the fracturing pump does not meet a preset pressure threshold includes: if the first liquid pressure information does not meet a preset first pressure information threshold, generating a first detection result of the fracturing pump being abnormal based on the first liquid pressure information; and if the second liquid pressure information does not meet a preset second pressure information threshold, generating a second detection result of the fracturing pump being abnormal based on the second liquid pressure information.

As shown in FIG. 6, the present disclosure provides a fracturing pump detection device 600, including a processor 111, a communication interface 112, a memory 113, and a communication bus 114. The processor 111, the communication interface 112, and the memory 113 communicate with each other through the communication bus 114. The memory 113 is configured to store a computer program. The processor 111 is configured to implement, when executing the program stored in the memory 113, the steps of the fracturing pump detection method provide in any one method embodiment of the present disclosure. In some implementations, the steps of the fracturing pump detection method may include the following steps: detecting stress information of pull rods of a fracturing pump through sensors at a power end of the fracturing pump; determining pump cavity liquid pressure information of the fracturing pump according to the stress information of the pull rods; and determining a detection result of the fracturing pump according to the pump cavity liquid pressure information and phase information of plungers corresponding to the stress information of the pull rods.

Further implementations of this disclosure are shown with reference to FIG. 7 to FIG. 19, describing embodiments for fluid leakage detection methods, applied to a hydraulic end of a fracturing device, to detect a leakage status of some structure of the hydraulic end of the fracturing pump.

The hydraulic end of the fracturing pump (e.g., a plunger pump), may include a valve assembly 7-100, and the valve assembly 7-100 includes an upper valve 7-110 and a lower valve 7-120. In addition, the hydraulic end may further include structures such as a valve box 7-200, a plunger 7-300, an end cover 7-400, a packing, and a liquid feeding pipeline 7-500. The valve box 7-200 may include a cavity, a liquid inlet channel, and a liquid outlet channel, the plunger 7-300 is movably arranged in the cavity, the packing is mounted at an end of the cavity, the upper valve 7-110 is arranged in the liquid outlet channel, and the lower valve 7-120 is arranged in the liquid inlet channel. Specifically, during pressurization and liquid discharge, the lower valve 7-120 is closed, and the upper valve 7-110 is opened, so that liquid pressurized in the valve box 7-200 is discharged through the liquid outlet channel; and during liquid feeding, the upper valve 7-110 is closed, and the lower valve 7-120 is opened, so that the liquid passes through the liquid feeding pipeline 7-500 and enters the valve box 7-200 through the liquid inlet channel, and the liquid is pressurized through the plunger 7-300.

The upper valve 7-110 and the lower valve 7-120 are opened and closed repeatedly during operation of the fracturing device, which determines that they are vulnerable parts. After operating for a long time, at least one of the upper valve 7-110 and the lower valve 7-120 may be damaged. As a result, seal fails and the function of the hydraulic end is abnormal.

Based on the foregoing situation, an embodiment of this application provides a fluid leakage detection method. At least one of the upper valve 7-110 and the lower valve 7-120 is detected, to provide basis information for repairing or replacing the valve assembly 7-100.

The disclosed detection method includes: collecting a change parameter of a fluid and/or a structure in the hydraulic end, and obtaining a corresponding change parameter time domain curve; comparing the change parameter time domain curve with a preset change parameter time domain curve; and determining a leakage status of the upper valve 7-110 and/or the lower valve 7-120 according to a phase change difference between the change parameter time domain curve and the preset change parameter time domain curve.

In the embodiments of this application, by collecting the change parameter of the fluid and/or the change parameter of the structure in the hydraulic end, the corresponding change parameter time domain curve may be obtained, and compared with the preset change parameter time domain curve, to the find the phase change difference, thereby determining a leakage position of the hydraulic end, and to help an operator make repair or replacement in time. Therefore, through the detection method in the embodiments of this application, a failed status of a valve can be identified in advance, so that a component such as the valve assembly 7-100 can be repaired or replaced in time before severe damage occur, the whole robustness of the hydraulic end can be ensured, its service life can be prolonged, and maintenance costs of the valve assembly 7-100 can be further reduced to some extent.

It should be noted herein that in the embodiments of this application, a corresponding time domain curve is obtained through the change parameter of the fluid and/or the change parameter of the structure in the hydraulic end that is actually detected, the corresponding time domain curve is compared with a preset time domain curve in a normal status (reference time-domain curves), and a leakage status of the valve assembly 7-100 is determined through a specific threshold according to a phase change difference between the corresponding time domain curve and the preset time domain curve.

A plurality of implementations of determining a detected leakage status of the valve assembly 7-100 are described below in detail below.

In some embodiments, a leakage status of the valve assembly 7-100 may be determined according to characteristics of the fluid in the hydraulic end, where the characteristics of the fluid may include a pressure fluctuation status, a flow fluctuation status, and the like of the fluid. The term “fluctuation” refers to time variance.

A first example implementation may include the change parameter of the fluid may include a fluid pressure fluctuation value, a fluid pressure fluctuation time domain curve is obtained according to the fluid pressure fluctuation value, and a leakage status of the upper valve 7-110 and/or the lower valve 7-120 is determined according to a phase change difference between the fluid pressure fluctuation time domain curve and a preset fluid pressure fluctuation time domain curve.

For example, the hydraulic end has a high-pressure region, and a pressure fluctuation value of the fluid in the high-pressure region may be detected. For example, the high-pressure region may be located in the cavity of the valve box 7-200, on the inner wall of the valve cover 7-400, or on the end face of the plunger 7-300, and may alternatively be in another position. This is not specifically limited in this embodiment of this application.

For example, it is determined that leakage occurs in the upper valve 7-110 when the fluid pressure fluctuation time domain curve in the high-pressure region has an advanced ascending edge (or ascending angle) and a delayed descending edge (or descending angle) compared with the preset fluid pressure fluctuation time domain curve, as shown in FIG. 8 and FIG. 11.

Further, a pore size of a leakage region of the upper valve 7-110 may correlate positively with an increase amplitude of each of the advances of the ascending edge (or ascending angle) and the delays in descending edge (or descending angle).

Specifically, when leakage occurs in the upper valve 7-110, it may be detected that the obtained fluid pressure fluctuation time domain curve has an advanced ascending edge (or ascending angle) and a delayed descending edge (or descending angle) compared with a normal fluid pressure fluctuation time domain curve (that is, the preset fluid pressure fluctuation time domain curve). In addition, as the pore size of the leakage region of the upper valve 7-110 increases, the time advance of the advanced ascending edge (or ascending angle) and the time delay in the delayed descending edge (or descending angle) of the pressure increases. To be specific, a larger pore size of leakage of the upper valve 7-110 may result in each of the ascending edge (or ascending angle) advance and the descending edge (or descending angle) delay of the pressure being larger. Therefore, it may be determined through a difference between the fluid pressure fluctuation time domain curve and the preset fluid pressure fluctuation time domain curve that leakage occurs in the upper valve 7-110, and the pore size of the leakage region may be further determined.

For another example, it may be determined that leakage occurs in the lower valve 7-120 when the fluid pressure fluctuation time domain curve in the high-pressure region has a delayed ascending edge (or ascending angle) and an advanced descending edge (or descending angle) compared with the preset fluid pressure fluctuation time domain curve, as shown in FIG. 9 and FIG. 12.

Further, a pore size of a leakage region of the lower valve 7-120 may correlate positively with an increase amplitude of each of the delays in the ascending edge (or ascending angle) and the advances in the descending edge (or descending angle).

Specifically, when leakage occurs in the lower valve 7-120, it may be detected that the obtained fluid pressure fluctuation time domain curve has a delayed ascending edge (or ascending angle) and an advanced descending edge (or descending angle) compared with a normal fluid pressure fluctuation time domain curve (that is, the preset fluid pressure fluctuation time domain curve). In addition, as the pore size of the leakage region of the lower valve 7-120 increases, each of the delays in the ascending edge (or ascending angle) and the advances in the descending edge (or descending angle) of the pressure increases. To be specific, a larger pore size of leakage of the lower valve 7-120 may result in each of the delay in ascending edge (or ascending angle) and the advance in the descending edge (or descending angle) of the pressure being larger. Therefore, it may be determined through a difference between the fluid pressure fluctuation time domain curve and the preset fluid pressure fluctuation time domain curve that leakage occurs in the lower valve 7-120, and the pore size of the leakage region may be further determined.

For another example, it is determined that leakage occurs in both the upper valve 7-110 and the lower valve 7-120 when the fluid pressure fluctuation time domain curve in the high-pressure region has an advanced ascending edge (or ascending angle) and an advanced descending edge (or descending angle) compared with the preset fluid pressure fluctuation time domain curve, as shown in FIG. 10 and FIG. 13.

Further, a pore size of a leakage region of the upper valve 7-110 may correlate positively with an increase amplitude of each of the advance in the ascending edge (or ascending angle) and the advance in the descending edge (or descending angle), and a pore size of a leakage region of the lower valve 7-120 correlates positively with an increase amplitude of each of the advance in the ascending edge (or ascending angle) and the advance in the descending edge (or descending angle).

Specifically, when leakage occurs in both the upper valve 7-110 and the lower valve 7-120, it may be detected that the obtained fluid pressure fluctuation time domain curve has an advanced ascending edge (or ascending angle) and an advanced descending edge (or descending angle) compared with a normal fluid pressure fluctuation time domain curve (that is, the preset fluid pressure fluctuation time domain curve). In addition, as the pore size of the leakage region of the upper valve 7-110 increases, each of the advance in the ascending edge (or ascending angle) and the advance in the descending edge (or descending angle) of the pressure increases. To be specific, a larger pore size of leakage of the upper valve 7-110 may result in each of the advance in the ascending edge (or ascending angle) and the advance in the descending edge (or descending angle) of the pressure being larger. In addition, as the pore size of the leakage region of the lower valve 7-120 increases, each of the advances in the ascending edge and the delay in the descending edge of the pressure increases. To be specific, a larger pore size of leakage of the lower valve 7-120 may result in each of the advance in the ascending edge and the delay in the descending edge of the pressure being larger. Therefore, it may be determined through a difference between the fluid pressure fluctuation time domain curve and the preset fluid pressure fluctuation time domain curve that leakage occurs in both the upper valve 7-110 and the lower valve 7-120, and the pore sizes of respective leakage regions are determined.

In the embodiments above of this disclosure, the hydraulic end may further have a low-pressure region, and a pressure fluctuation value of the fluid in the low-pressure region is detected. For example, the low-pressure region may be located at the entrance of the lower valve 7-120 or in the liquid feeding pipeline 7-500, and may alternatively be in another position. This is not specifically limited in this embodiment of this application. The pressure of the fluid in the foregoing low-pressure region is total pressure of the fluid in the region, that is, a sum of dynamic pressure of the fluid and static pressure of the fluid.

For example, it may be determined that leakage occurs in the upper valve 7-110 when the fluid pressure fluctuation time domain curve in the low-pressure region has an advanced ascending edge (or ascending angle) and a delayed descending edge (or descending angle) compared with the preset fluid pressure fluctuation time domain curve and a descending branch has an abrupt change, as shown in FIG. 14.

Further, a pore size of a leakage region of the upper valve 7-110 correlates positively with an increase amplitude of each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle).

Specifically, when leakage occurs in the upper valve 7-110, it may be detected that the obtained fluid pressure fluctuation time domain curve has an advanced ascending edge (or ascending angle) and a delayed descending edge (or descending angle) compared with a normal fluid pressure fluctuation time domain curve (that is, the preset fluid pressure fluctuation time domain curve), and the descending edge may have an abrupt change in some situations. In addition, as the pore size of the leakage region of the upper valve 7-110 increases, each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle) of the pressure increases. To be specific, a larger pore size of leakage of the upper valve 7-110 may results int each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle) of the pressure being larger. Therefore, it may be determined through a difference between the fluid pressure fluctuation time domain curve and the preset fluid pressure fluctuation time domain curve that leakage occurs in the upper valve 7-110, and the pore size of the leakage region may be further determined. It should be noted herein that when the pore size of the upper valve 7-110 is greater than a threshold, the obtained fluid pressure fluctuation time domain curve may have an abrupt change in pressure.

For example, it may be determined that leakage occurs in the lower valve 7-120 when the fluid pressure fluctuation time domain curve in the low-pressure region has an advanced ascending edge (or ascending angle) compared with the preset fluid pressure fluctuation time domain curve and a advance or delay in the descending edge (or descending angle) is zero or approaches zero, as shown in FIG. 15.

Further, a pore size of a leakage region of the lower valve 7-120 correlates positively with an increase amplitude of the advance in the ascending edge (or ascending angle).

Specifically, when leakage occurs in the lower valve 7-120, it may be detected that the obtained fluid pressure fluctuation time domain curve has an advanced ascending edge (or ascending angle) compared with a normal fluid pressure fluctuation time domain curve (that is, the preset fluid pressure fluctuation time domain curve), and a advance or delay in the descending edge (or descending angle) is zero or approaches zero. In addition, as the pore size of the leakage region of the lower valve 7-120 increases, the advance in the ascending edge (or ascending angle) of the pressure increases and the advance or delay in the descending edge (or descending angle) does not change significantly. To be specific, a larger pore size of the leakage region of the lower valve 7-120 may result in that the advance in the ascending edge (or ascending angle) (an average value of an ascending branch of the pressure) of the pressure being larger and the advance or delay in the descending edge (or descending angle) of the pressure not being changed significantly. Therefore, it may be determined through a difference between the fluid pressure fluctuation time domain curve and the preset fluid pressure fluctuation time domain curve that leakage occurs in the lower valve 7-120, and the pore size of the leakage region may be further determined.

For example, it may be determined that leakage occurs in both the upper valve 7-110 and the lower valve 7-120 when the fluid pressure fluctuation time domain curve in the low-pressure region has an advanced ascending edge (or ascending angle) and a delayed descending edge (or descending angle) compared with the preset fluid pressure fluctuation time domain curve, as shown in FIG. 16.

Further, a pore size of a leakage region of the upper valve 7-110 correlates positively with an increase amplitude of each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle), and a pore size of a leakage region of the lower valve 7-120 correlates positively with an increase amplitude of each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle).

Specifically, when leakage occurs in both the upper valve 7-110 and the lower valve 7-120, it may be detected that the obtained fluid pressure fluctuation time domain curve has an advanced ascending edge (or ascending angle) and a delayed descending edge (or descending angle) compared with a normal fluid pressure fluctuation time domain curve (that is, the preset fluid pressure fluctuation time domain curve). In addition, as the pore size of the leakage region of the upper valve 7-110 increases, each of the advanced ascending edge (or ascending angle) and the delay in the descending edge (or descending angle) of the pressure increases. To be specific, a larger pore size of leakage of the upper valve 7-110 may result in each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle) of the pressure being larger. In addition, as the pore size of the leakage region of the lower valve 7-120 increases, each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle) of the pressure increases. To be specific, a larger pore size of leakage of the lower valve 7-120 may result in each of the advance in the ascending edge and the delay in the descending edge of the pressure being larger. Therefore, it may be determined through a difference between the fluid pressure fluctuation time domain curve and the preset fluid pressure fluctuation time domain curve that leakage occurs in both the upper valve 7-110 and the lower valve 7-120, and the pore sizes of respective leakage regions may be further determined.

A second example implementation may include: the change parameter of the fluid may include a fluid flow fluctuation value, a fluid flow fluctuation time domain curve is obtained according to the fluid flow fluctuation value, and a leakage status of the upper valve 7-110 and/or the lower valve 7-120 may be determined according to a phase change difference between the fluid flow fluctuation time domain curve and a preset fluid flow fluctuation time domain curve. For example, a fluid flow fluctuation value at the entrance of the lower valve 7-120, and alternatively in another position, for example, in the liquid feeding pipeline 7-500, may be detected, to obtain a fluid flow fluctuation time domain curve. This is not specifically limited in this embodiment of this disclosure.

For example, it may be determined that leakage occurs in the upper valve 7-110 when the fluid flow fluctuation time domain curve has a delayed ascending edge (or ascending angle) and an advanced descending edge (or descending angle) compared with the preset fluid flow fluctuation time domain curve, as shown in FIG. 17.

Further, a pore size of a leakage region of the upper valve 7-110 correlates positively with an increase amplitude of each of the delay in the ascending edge (or ascending angle) and the advance in the descending edge (or descending angle).

When leakage occurs in the upper valve 7-110, it may be found during opening of the lower valve 7-120 that as the pore size of the leakage region of the upper valve 7-110 increases, the instantaneous flow at the entrance of the lower valve 7-120 ascends with delay and descends with time advance, that is, the flow has a delayed ascending edge (or ascending angle) and an advanced descending edge (or descending angle). In addition, as the pore size of the leakage region of the upper valve 7-110 increases, each of the delay in the ascending edge (or ascending angle) and the advance in the descending edge (or descending angle) of the flow increases. To be specific, a larger pore size may result in each of the delay in the ascending edge (or ascending angle) and the advance in the descending edge (or descending angle) of the instantaneous flow being larger. In addition, an average value of the instantaneous flow at the entrance in the whole process increases. Therefore, it may be determined through a difference between the fluid flow fluctuation time domain curve and the preset fluid flow fluctuation time domain curve that leakage occurs in the upper valve 7-110, and the pore size of the leakage region may be further determined.

For another example, it may be determined that leakage occurs in the lower valve 7-120 when the fluid flow fluctuation time domain curve has an advanced ascending edge (or ascending angle) compared with the preset fluid flow fluctuation time domain curve and has a reverse leakage, as shown in FIG. 18.

Further, a pore size of a leakage region of the lower valve 7-120 correlates positively with each of the advance in the ascending edge (or ascending angle) and an absolute value of flow of the reverse leakage.

Specifically, when leakage occurs in the lower valve 7-120, it may be found that there is reverse leakage at the entrance of the lower valve 7-120 before the lower valve 7-120 is opened, and an absolute value of the leakage flow increases as the pore size of the leakage region of the lower valve 7-120 increases; and there is reverse liquid flushing flow at the entrance of the lower valve 7-120 after the lower valve 7-120 is closed, and an absolute value of the leakage flow increases as the pore size of the leakage region of the lower valve 7-120 increases. In addition, during opening of the lower valve 7-120, the instantaneous flow at the entrance of the lower valve 7-120 ascends in advance. To be specific, a larger pore size of the leakage of the lower valve 7-120 may results in a larger advance in the ascending edge (or ascending angle) of the instantaneous flow. Therefore, it may be determined through a difference between the fluid flow fluctuation time domain curve and the preset fluid flow fluctuation time domain curve that leakage occurs in the lower valve 7-120, and the pore size of the leakage region may be further determined.

For another example, it is determined that leakage occurs in both the upper valve 7-110 and the lower valve 7-120 when the fluid flow fluctuation time domain curve has an advanced descending edge (or descending angle) compared with the preset fluid flow fluctuation time domain curve and has reverse leakage, as shown in FIG. 19.

Further, a pore size of a leakage region of the upper valve 7-110 correlates positively with an increase amplitude of each of the advance in the descending edge (or descending angle) and an absolute value of flow of the reverse leakage, and a pore size of a leakage region of the lower valve 7-120 correlates positively with an increase amplitude of each of the advance in the descending edge (or descending angle) and an absolute value of flow of the reverse leakage.

Specifically, when leakage occurs in both the upper valve 7-110 and the lower valve 7-120, it may be found that there is reverse leakage close to the entrance of the lower valve 7-120 before the lower valve 7-120 is opened and there is similarly reverse leakage at the entrance of the lower valve 7-120 after the lower valve 7-120 is closed. In addition, when the lower valve 7-120 is opened, the instantaneous flow descends with delay. Therefore, it may be determined through a difference between the fluid flow fluctuation time domain curve and the preset fluid flow fluctuation time domain curve that leakage occurs in both the upper valve 7-110 and the lower valve 7-120, and the pore size of the leakage region may be further determined.

An third example implementation may include the change parameter of the structure may include a structural stress fluctuation value, a structural stress fluctuation time domain curve is obtained according to the structural stress fluctuation value, and a leakage status of the upper valve 7-110 and/or the lower valve 7-120 may be determined according to a phase change difference between the structural stress fluctuation time domain curve and a preset structural stress fluctuation time domain curve.

For example, the hydraulic end has a high-pressure region, and a structural stress fluctuation value in the high-pressure region may be detected. For example, the high-pressure region may be located on the inner wall of the cavity of the valve box 7-200, the end face of the plunger 7-300, or the inner wall of the end cover 7-400, and may alternatively be in another position. This is not specifically limited in this embodiment of this application.

For example, it may be determined that leakage occurs in the upper valve 7-110 when the structural stress fluctuation time domain curve in the high-pressure region has an advanced ascending edge (or ascending angle) and a delayed descending edge (or descending angle) compared with the preset structural stress fluctuation time domain curve.

Further, a pore size of a leakage region of the upper valve 7-110 correlates positively with an increase amplitude of each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle).

Specifically, when leakage occurs in the upper valve 7-110, it may be detected that the obtained structural stress fluctuation time domain curve has an advanced ascending edge (or ascending angle) and a delayed descending edge (or descending angle) compared with a normal structural stress fluctuation time domain curve (that is, the preset structural stress fluctuation time domain curve). In addition, as the pore size of the leakage region of the upper valve 7-110 increases, each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle) of the stress increases. To be specific, a larger pore size of leakage of the upper valve 7-110 may result in that each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle) of the stress being larger. Therefore, it may be determined through a difference between the structural stress fluctuation time domain curve and the preset structural stress fluctuation time domain curve that leakage occurs in the upper valve 7-110, and the pore size of the leakage region may be further determined.

For another example, it may be determined that leakage occurs in the lower valve 7-120 when the structural stress fluctuation time domain curve in the high-pressure region has a delayed ascending edge (or ascending angle) and an advanced descending edge (or descending angle) compared with the preset structural stress fluctuation time domain curve.

Further, a pore size of a leakage region of the lower valve 7-120 correlates positively with an increase amplitude of each of the delay in the ascending edge (or ascending angle) and the advance in the descending edge (or descending angle).

Specifically, when leakage occurs in the lower valve 7-120, it may be detected that the obtained structural stress fluctuation time domain curve has a delayed ascending edge (or ascending angle) and an advanced descending edge (or descending angle) compared with a normal structural stress fluctuation time domain curve (that is, the preset structural stress fluctuation time domain curve). In addition, as the pore size of the leakage region of the lower valve 7-120 increases, each of the delay in the ascending edge (or ascending angle) and the advance in the descending edge (or descending angle) of the stress increases. To be specific, a larger pore size of leakage of the lower valve 7-120 may result in each of the delay in the ascending edge (or ascending angle) and the advance in the descending edge (or descending angle) of the stress being larger. Therefore, it may be determined through a difference between the structural stress fluctuation time domain curve and the preset structural stress fluctuation time domain curve that leakage occurs in the lower valve 7-120, and the pore size of the leakage region may be further determined.

For another example, leakage occurs in both the upper valve 7-110 and the lower valve 7-120 may result in the structural stress fluctuation time domain curve in the high-pressure region having an advanced ascending edge (or ascending angle) and a delayed descending edge (or descending angle) compared with the preset structural stress fluctuation time domain curve.

Further, a pore size of a leakage region of the upper valve 7-110 correlates positively with an increase amplitude of each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle), and a pore size of a leakage region of the lower valve 7-120 correlates positively with an increase amplitude of each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle).

Specifically, when leakage occurs in both the upper valve 7-110 and the lower valve 7-120, it may be detected that the obtained structural stress fluctuation time domain curve has an advanced ascending edge (or ascending angle) and a delayed descending edge (or descending angle) compared with a normal structural stress fluctuation time domain curve (that is, the preset structural stress fluctuation time domain curve). As the pore size of the leakage region of the upper valve 7-110 increases, each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle) of the stress increases. To be specific, a larger pore size of leakage of the upper valve 7-110 may result in each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle) of the stress being larger. In addition, as the pore size of the leakage region of the lower valve 7-120 increases, each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle) of the stress increases. To be specific, a larger pore size of leakage of the lower valve 7-120 may result in each of the advance in the ascending edge (or ascending angle) and the delay in the descending edge (or descending angle) of the stress being larger. Therefore, it may be determined through a difference between the structural stress fluctuation time domain curve and the preset structural stress fluctuation time domain curve that leakage occurs in both the upper valve 7-110 and the lower valve 7-120, and the pore sizes of respective leakage regions may be further determined.

In the example embodiments above, the hydraulic end may further have a low-pressure region, and a structural stress fluctuation value in the low-pressure region is detected. For example, the low-pressure region may be located at the entrance of the lower valve 7-120, and may alternatively be in another position. This is not specifically limited in this embodiment of this disclosure.

In the various example implementations above, the term “advance” is used to refer to “time advance” and the term “delay” is used to refer to “time delay” in the corresponding time-domain curves.

It should be noted herein that when fluid flow around a cylinder, it may be described according to the Navier-Stokes vector equation

$\frac{d\underset{v}{\to }}{\mathrm{dt}}=-\nabla p+\rho \underset{F}{\to }+\mathrm{\mu \Delta }\underset{v}{\to },$

where a dynamic pressure of the fluid may be converted to a static pressure, e.g., a dynamic pressure fluctuation may be converted to stress strain fluctuation. A stress strain sensor 7-630 may be arranged, to detect a stress strain fluctuation status of a local dynamic pressure at the entrance of the lower valve 7-120, to provide the basis for determining leakage of the valve assembly 7-100.

For example, it may be determined that leakage occurs in the upper valve 7-110 when the structural stress fluctuation time domain curve in the low-pressure region has a time advance in stress change edge and/or a time delay in stress edge compared with the preset structural stress fluctuation time domain curve.

Specifically, when leakage occurs in the upper valve 7-110, it may be deduced according to the fluid flow fluctuation time domain curve that there are a time advance and/or time delay in the stress change edge. In addition, as the pore size of the leakage region of the upper valve 7-110 increases, each of the time advance and/or time delay in the stress change edge may increase.

For another example, it may be determined that leakage has occurred in the lower valve 7-120 when the structural stress fluctuation time domain curve in the low-pressure region has a time advance in the stress change edge compared with the preset structural stress fluctuation time domain curve and has a stress fluctuation value when the lower valve 7-120 is closed.

Specifically, when leakage occurs in the lower valve 7-120, it may be deduced according to the fluid flow fluctuation time domain curve that when the lower valve 7-120 is closed, a stress fluctuation change occurs and there is a time advance in the stress change edge. In addition, as the pore size of the leakage region of the lower valve 7-120 increases, the time advance in the stress change edge may increase, and a time delay in the stress change edge may not occur.

For another example, it may be determined that leakage has occurred in both the upper valve 7-110 and the lower valve 7-120 when the structural stress fluctuation time domain curve in the low-pressure region has a time delay in the stress change edge compared with the preset structural stress fluctuation time domain curve and has a stress fluctuation value in a case that the lower valve 7-120 is closed.

Specifically, when leakage occurs in both the upper valve 7-110 and the lower valve 7-120, and when the lower valve 7-120 is closed, a stress fluctuation change occurs and there may be a time delay in the stress change edge. In addition, as the pore sizes of the leakage regions of the upper valve 7-110 and the lower valve 7-120 increase, a time advance in the stress change edge may not occur, and the time delay in the stress change edge may increase.

Based on the foregoing fluid leakage detection method, an embodiment of this application further discloses a fracturing device, to which the foregoing fluid leakage detection method is applied, to detect and determine a leakage status of a hydraulic end of the fracturing device through the foregoing detection method.

The disclosed fracturing device may include a hydraulic end, a first detection element and/or a second detection element, and a control element, where the hydraulic end includes a valve assembly 7-100, the valve assembly 7-100 includes an upper valve 7-110 and a lower valve 7-120, the first detection element is configured to collect a change parameter of a fluid in the hydraulic end, and the second detection element is configured to collect a change parameter of a structure in the hydraulic end.

The control element is electrically connected to the first detection element and/or the second detection element. The control element is configured to perform control to collect the change parameter of the fluid and/or the structure in the hydraulic end, and generate a change parameter time domain curve. The control element is further configured to compare the change parameter time domain curve with a preset change parameter time domain curve; and to determine a leakage status of the upper valve 7-110 and/or the lower valve 7-120 according to a phase change difference between the change parameter time domain curve and the preset change parameter time domain curve.

Specifically, the control element may receive the change parameter of the fluid in the hydraulic end that is collected by the first detection element, for example, a fluid stress change parameter or a fluid flow change parameter, generate a fluid change parameter time domain curve, compare the fluid change parameter time domain curve with a preset fluid change parameter time domain curve, determine a phase change difference between the two curves, and determine the leakage status of the upper valve 7-110 and/or the lower valve 7-120 according to the difference.

The control element may further receive the change parameter of the structure in the hydraulic end that is collected by the second detection element, for example, a structural stress change parameter, generate a structure change parameter time domain curve, compare the structure change parameter time domain curve with a preset fluid change parameter time domain curve, determine a phase change difference between the two curves, and determine the leakage status of the upper valve 7-110 and/or the lower valve 7-120 according to the difference.

In some example embodiments, the first detection element may be a pressure sensor 7-610, and the pressure sensor 7-610 may be arranged in a high-pressure region or a low-pressure region of the hydraulic end.

Specifically, the hydraulic end may include a valve box 7-200 and an end cover 7-400, and a plunger 7-300 may be arranged in the valve box 7-200. During operation of the fracturing device, regions such as an inner wall of a cavity of the valve box 7-200, an end face of the plunger 7-300, and an inner wall of the end cover 7-400 may all be in contact with the compressed high-pressure fluid, and may all be located in the high-pressure region. Based on this, the pressure sensor 7-610 may be arranged on at least one region such as the inner wall of the cavity of the valve box 7-200, the inner wall of the end cover 7-400, or the end face of the plunger 7-300, to detect a fluid pressure fluctuation change in the high-pressure region of the hydraulic end.

In addition, the fluid may enter the hydraulic end through the entrance of the lower valve 7-120, and the entrance may be isolated from the cavity of the valve box 7-200 through the lower valve 7-120. Therefore, the entrance of the lower valve 7-120 may be a low-pressure region, and the pressure sensor 7-610 may alternatively be arranged at the entrance of the lower valve 7-120, to detect a fluid pressure fluctuation change of the low-pressure region of the hydraulic end.

In some other example embodiments, the first detection element may alternatively be a flow sensor 7-620, and the flow sensor 7-620 may be arranged in the low-pressure region of the hydraulic end.

Specifically, the fluid may enter the hydraulic end through the entrance of the lower valve 7-120, and the entrance may be isolated from the cavity of the valve box 7-200 through the lower valve 7-120. Therefore, the entrance of the lower valve 7-120 may be a low-pressure region, and the flow sensor 7-620 may alternatively be arranged at the entrance of the lower valve 7-120, to detect a fluid flow fluctuation change of the low-pressure region of the hydraulic end.

In some embodiments, the second detection element may be a stress strain sensor 7-630, and the stress strain sensor 7-630 may be arranged in a high-pressure region or a low-pressure region of the hydraulic end.

Specifically, the fracturing device may include a driving mechanism, and the driving mechanism may include a crankshaft, a first connecting rod, a crosshead, a second connecting rod, and a plunger 7-300 that are connected sequentially. During operation of the fracturing device, each of the crankshaft, the first connecting rod, the crosshead, the second connecting rod, and the plunger 7-300 bears a large load, and therefore generates relatively large deformation. Based on this, the stress strain sensor 7-630 may be arranged on at least one of the crankshaft, the first connecting rod, the crosshead, the second connecting rod, and the plunger 7-300, to detect a structural stress fluctuation change in the high-pressure region of the hydraulic end.

In addition, the fluid may enter the hydraulic end through the entrance of the lower valve 7-120, and the entrance may be isolated from the cavity of the valve box 7-200 through the lower valve 7-120. Therefore, the entrance of the lower valve 7-120 may be a low-pressure region, and bears a small load, so that the region generates relatively small deformation. Based on this, the stress strain sensor 7-630 is arranged at the entrance of the lower valve 7-120, to detect a structural stress fluctuation change of the low-pressure region of the hydraulic end.

In the example embodiments of this disclosure, the fracturing device may further include a liquid feeding pipeline 7-500, and an exit of the liquid feeding pipeline 7-500 may be connected to the entrance of the lower valve 7-120, so that the inside of the liquid feeding pipeline 7-500 is similarly in the low-pressure region. Based on this, at least one of the pressure sensor 7-610, the flow sensor 7-620, and the stress strain sensor 7-630 may alternatively be arranged inside the liquid feeding pipeline 7-500, to detect at least one of the fluid pressure, the fluid flow, and the structural stress of the inside.

It should be noted herein that for each of analysis principles of the detection of the change parameters of the fluid pressure, the fluid flow, and the structural stress in the hydraulic end of the fracturing device in this embodiment of this disclosure and the comparison between the change parameter time domain curves, and the determination of the leakage status of the upper valve 7-110 and/or the lower valve 7-120, reference may be made to corresponding content in the foregoing fluid leakage detection method. Details are not described herein again.

As such, by collecting the change parameter of the fluid and/or the change parameter of the structure in the hydraulic end, the change parameter time domain curve may be obtained, and compared with the preset change parameter time domain curve, to the find the difference, thereby determining a leakage position of the hydraulic end, to help an operator make repair or replacement in time. Based on this, through the detection method in the embodiments of this disclosure, a failure of a valve can be identified in advance, so that a component such as the valve assembly 7-100 can be repaired or replaced in time before severe damage occur. The overall robustness of the hydraulic end can be improved, its service life can be prolonged, and maintenance costs of the valve assembly 7-100 can be further reduced.

According at least one of the embodiments above, a fluid leakage detection method is disclosed. The method may be applied to a hydraulic end of a fracturing device such as a plunger pump. The hydraulic end may include a valve assembly. The valve assembly comprises an upper valve and a lower valve. The leakage detection method may include: collecting a change parameter of a fluid and/or a structure in the hydraulic end, and obtaining a corresponding change parameter time domain curve; comparing the change parameter time domain curve with a preset change parameter time domain curve; and determining a leakage status of the upper valve and/or the lower valve according to a phase change difference between the change parameter time domain curve and the preset change parameter time domain curve.

In the example implementation above, the change parameter of the fluid in the hydraulic end comprises a fluid pressure value, and a fluid pressure time domain curve may be obtained according to the fluid pressure value as a function time; and a leakage status of the upper valve and/or the lower valve is determined according to a phase change difference between the fluid pressure time domain curve and a preset fluid pressure time domain curve.

In any one of the example implementations above, the hydraulic end may contain a high-pressure region for fracturing fluid. It may be determined that leakage has occurred in the upper valve when the fluid pressure time domain curve in the high-pressure region has a time-advanced ascending edge and a time-delayed descending edge compared with the preset fluid pressure time domain curve. It may be determined that leakage occurs in the lower valve when the fluid pressure time domain curve in the high-pressure region has a time-delayed ascending edge and a time-advanced descending edge compared with the preset fluid pressure time domain curve. It may be determined that leakage occurs in both the upper valve and the lower valve when the fluid pressure time domain curve in the high-pressure region has a time-advanced ascending edge and a time-advanced descending edge compared with the preset fluid pressure time domain curve.

In any one of the example implementations above, a pore size of a leakage region of the upper valve correlates positively with an increase amplitude of each of the time advance in the ascending edge and the time delay in the descending edge. Alternatively, the pore size of a leakage region of the lower valve correlates positively with an increase amplitude of each of the time delay in the ascending edge and the time advance in the descending edge. Alternatively, the pore size of a leakage region of the upper valve correlates positively with an increase amplitude of each of the time advance in the ascending edge and the time advance in the descending edge, and a pore size of a leakage region of the lower valve correlates positively with an increase amplitude of each of the time advance in the ascending edge and the time advance in the descending edge.

In any one of the example implementations above, the hydraulic end has a low-pressure region. It may be determined that leakage occurs in the upper valve when the fluid pressure time domain curve in the low-pressure region has a time-advanced ascending edge and a time-delayed descending edge compared with the preset fluid pressure time domain curve and a descending branch has an abrupt change. Alternatively, it may be determined that leakage occurs in the lower valve when the fluid pressure time domain curve in the low-pressure region has a time-advanced ascending edge compared with the preset fluid pressure time domain curve and a time delay in the descending edge is zero or approaches zero. Alternatively, it may be determined that leakage occurs in both the upper valve and the lower valve when the fluid pressure time domain curve in the low-pressure region has a time-advanced ascending edge and a time-delayed descending edge compared with the preset fluid pressure time domain curve.

In the example implementations above, a pore size of a leakage region of the upper valve correlates positively with an increase amplitude of each of the time advance in the ascending edge and the time delay in the descending edge. Alternatively, the pore size of a leakage region of the lower valve correlates positively with an increase amplitude of the time advance in the ascending edge. Alternatively, the pore size of a leakage region of the upper valve correlates positively with an increase amplitude of each of the time advance in the ascending edge and the time delay in the descending edge, and a pore size of a leakage region of the lower valve correlates positively with an increase amplitude of each of the time advance in the ascending edge and the time delay in the descending edge.

In any one of the example implementations above, the change parameter of the fluid in the hydraulic end comprises a fluid flow value at an entrance of the lower valve, and a fluid flow time domain curve is obtained according to the fluid flow value; and a leakage status of the upper valve and/or the lower valve is determined according to a phase change difference between the fluid flow time domain curve and a preset fluid flow time domain curve.

In the example implementation above, it may be determined that leakage occurs in the upper valve when the fluid flow time domain curve has a time-delayed ascending edge and a time-advanced descending edge compared with the preset fluid flow time domain curve. It may be further determined that leakage occurs in the lower valve when the fluid flow time domain curve has a time-advanced ascending edge compared with the preset fluid flow time domain curve and has reverse leakage. It may further be determined that leakage occurs in both the upper valve and the lower valve when the fluid flow time domain curve has a time-advanced descending edge compared with the preset fluid flow time domain curve and has reverse leakage.

In the example implementation above, a pore size of a leakage region of the upper valve correlates positively with an increase amplitude of each of the time delay in the ascending edge and the time advance in the descending edge. Alternatively, the pore size of a leakage region of the lower valve correlates positively with each of the time advance in the ascending edge and an absolute value of flow of the reverse leakage. Alternatively, the pore size of a leakage region of the upper valve correlates positively with an increase amplitude of each of the time advance in the descending edge and an absolute value of flow of the reverse leakage, and a pore size of a leakage region of the lower valve correlates positively with an increase amplitude of each of the time advance in the descending edge and an absolute value of flow of the reverse leakage.

In any one of the example implementations above, the change parameter of the structure in the hydraulic end comprises a structural stress value, and a structural stress time domain curve is obtained according to the structural stress value; and a leakage status of the upper valve and/or the lower valve is determined according to a phase change difference between the structural stress time domain curve and a preset structural stress time domain curve.

In the example implementation above, the hydraulic end has a high-pressure region. It may be determined that leakage occurs in the upper valve or leakage occurs in both the upper valve and the lower valve when the structural stress time domain curve in the high-pressure region has a time advance in the ascending edge and a time-delay in the descending edge compared with the preset structural stress time domain curve. It may further be determined that leakage occurs in the lower valve when the structural stress time domain curve in the high-pressure region has a time delay in the ascending edge and a time advance in the descending edge compared with the preset structural stress time domain curve.

In the example implementation above, a pore size of a leakage region of the upper valve correlates positively with an increase amplitude of each of the time advance in the ascending edge and the time delay in the descending edge. Alternatively, the pore size of a leakage region of the lower valve correlates positively with an increase amplitude of each of the time delay in the ascending edge and the time advance in the descending edge. Alternatively, the pore size of a leakage region of the upper valve correlates positively with an increase amplitude of each of the time advance in the ascending edge and the time delay in the descending edge, and a pore size of a leakage region of the lower valve correlates positively with an increase amplitude of each of the time advance in the ascending edge and the time delay in the descending edge.

In any one of the example implementations above, the hydraulic end has a low-pressure region. It may be determined that leakage occurs in the upper valve when the structural stress time domain curve in the low-pressure region has a time advance in stress change edge and/or a time delay in stress edge compared with the preset structural stress time domain curve. It may further be determined that leakage occurs in the lower valve when the structural stress time domain curve in the low-pressure region has a time advance in stress change edge compared with the preset structural stress time domain curve and has a stress fluctuation value when the lower valve is closed. It may further be determined that leakage occurs in both the upper valve and the lower valve when the structural stress time domain curve in the low-pressure region has a time delay in stress edge compared with the preset structural stress time domain curve and has a stress value in when the lower valve is closed.

In some other example implementations, a fracturing device is disclosed. The fracturing device may be configured to implement the leakage detection method according to any one of implementations above. Such a fracturing device may include: a hydraulic end, a first detection element and/or a second detection element, and a control element. The hydraulic end comprises a valve assembly, and the valve assembly comprises an upper valve and a lower valve. The first detection element is configured to collect a change parameter of a fluid in the hydraulic end, and the second detection element is configured to collect a change parameter of a structure in the hydraulic end. The control element is configured to: perform control to collect the change parameter of the fluid and/or the structure in the hydraulic end, and obtain a corresponding change parameter time domain curve; compare the change parameter time domain curve with a preset change parameter time domain curve; and determine a leakage status of the upper valve and/or the lower valve according to a phase change difference between the change parameter time domain curve and the preset change parameter time domain curve.

In the example implementation above, the hydraulic end comprises a valve box and an end cover, and a plunger is arranged in the valve box; and the first detection element is a pressure sensor, and the pressure sensor is arranged at least on an inner wall of a cavity of the valve box, or on an inner wall of the end cover, or on an end face of the plunger, or at an entrance of the lower valve.

In any one of the example implementations above, the first detection element is a flow sensor, and the flow sensor is arranged at an entrance of the lower valve.

In any one of the example implementations above, the fracturing device further comprises a driving mechanism, and the driving mechanism comprises a crankshaft, a first connecting rod, a crosshead, a second connecting rod, and a plunger that are connected sequentially; and the second detection element is a stress strain sensor, and the stress strain sensor is arranged at least on the crankshaft, on the first connecting rod, on the crosshead, on the second connecting rod, on the plunger, or at an entrance of the lower valve.

It is to be noted that, the fracturing pump detection systems provided in the example embodiments of the present disclosure may perform the fracturing pump detection method provided in any embodiment of the present disclosure, and has corresponding functions and beneficial effects of the performed method.

In some implementations, the foregoing fracturing pump detection system may detect stress information of pull rods through sensors at a power end of a fracturing pump, to determine a detection result of the fracturing pump, and/or to detect leakage of the hydraulic end The fracturing pump detection system may be formed by two or more physical entities, or may be formed by one physical entity. For example, a device may be a personal computer (PC), a computer, a server, or the like. This is not specifically limited in the embodiments of the present disclosure.

The present disclosure further provides a computer-readable storage medium, having a computer program stored therein, where the computer program, when being executed by a processor, implements the fracturing pump detection method provided in the present disclosure.

It should be noted that the relational terms herein such as “first” and “second” are used only to differentiate an entity or operation from another entity or operation, and do not require or imply any actual relationship or sequence between these entities or operations. Moreover, the terms “include,” “comprise,” and any variation thereof are intended to cover a non-exclusive inclusion. Therefore, in the context of a process, a method, an object, or a device that includes a series of elements, the process, method, object, or device not only includes such elements, but also includes other elements not specified expressly, or may include inherent elements of the process, method, object, or device. If no more limitations are made, an element limited by “include a/an . . . ” does not exclude other same elements existing in the process, the method, the article, or the device which includes the element.

The foregoing are only specific implementations of the present disclosure to enable a person skilled in the art to understand or implement the present disclosure. It is apparent to a person skilled in the art to make various changes to these embodiments. The general concept defined in this specification may be implemented in other embodiments without departing from the spirit and scope of the present disclosure. Therefore, the present disclosure is not limited to these embodiments illustrated herein, but needs to conform to the broadest scope consistent with the principles and novel features disclosed in the present invention.

Claims

1. A fracturing pump operation fault detection method, comprising: detecting stress information in a pull rod of a fracturing pump through a sensor installed at a power end of the fracturing pump, the sensor being isolated from fracturing liquid displaced by the fracturing pump;determining pump cavity liquid pressure information of the fracturing pump according to the stress information of the pull rod;determining phase information of a plunger corresponding to the stress information of the pull rod; anddetermining a detection result of the fracturing pump according to the pump cavity liquid pressure information and phase information of the plunger.

2. The method according to claim 1, wherein the sensor installed at the power end comprises a tension sensor mounted at the pull rod of the fracturing pump, and detecting the stress information in the pull rod of a fracturing pump comprises: obtaining end tension information of the pull rod as detected by the tension sensor; anddetermining the stress information of the pull rod based on the end tension information in the pull rod and preset end cross-sectional area information of the pull rod.

3. The method according to claim 1, wherein the sensor at the power end comprises a strain sensor mounted at the pull rod, and detecting the stress information in the pull rod comprises: obtaining end strain information of the pull rod as detected by the strain sensor; anddetermining the stress information of the pull rod based on the end strain information in the pull rod, preset elastic modulus information of a material associated with the pull rod, and preset end cross-sectional area information of the pull rod.

4. The method according to claim 1, wherein determining the pump cavity liquid pressure information of the fracturing pump according to the stress information of the pull rod comprises: obtaining piston cross-sectional area information of the fracturing pump associated with the pull rod; andperforming calculation based on the piston cross-sectional area information and the stress information of the pull rod, to obtain the pump cavity liquid pressure information of the fracturing pump.

5. The method according to claim 1, wherein determining the detection result of the fracturing pump according to the pump cavity liquid pressure information and phase information of the plunger comprises: determining the phase information of the plunger corresponding to the stress information of the pull rod;detecting whether the pump cavity liquid pressure information is consistent with the phase information of the plunger;determining liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the phase information of the plunger if the pump cavity liquid pressure information is consistent with the phase information of the plunger; andgenerating an abnormal detection result for the fracturing pump if the liquid pressure information of the fracturing pump does not meet a preset pressure threshold.

6. The method according to claim 5, wherein determining the liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the phase information of the plunger comprises: if the phase information of the plunger belongs to first phase information of the plunger, determining the liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the first phase information of the plunger; andif the phase information of the plunger belongs to second phase information of the plunger, determining the liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the second phase information of the plunger.

7. The method according to claim 6, wherein after generating the abnormal detection result of the fracturing pump, the method further comprises: triggering an output of alarm information based on the abnormal detection result, whereingenerating the abnormal detection result comprises: if the liquid pressure information does not meet a preset first pressure information threshold, generating a first detection result indicating that the fracturing pump is abnormal for a first reason; and if the liquid pressure information does not meet a preset second pressure information threshold, generating a second detection result indicating that the fracturing pump is abnormal for a second reason.

8. A fracturing pump operation fault detection system, comprising: a pull rod stress detection sensor installed on a pull rod of a fracturing pump at a power end of the fracturing pump, the pull rod stress detection sensor being configured to detect stress information of the pull rod;a pump cavity liquid pressure information processing circuitry configured to: determine pump cavity liquid pressure information of the fracturing pump according to the stress information of the pull rod as detected by the pull rod stress detection sensor; anddetermine an operation fault detection result of the fracturing pump according to the pump cavity liquid pressure information and phase information of a plunger associated with the pull rod corresponding to the stress information of the pull rod.

9. The fracturing pump operation fault detection system according to claim 8, wherein the pull rod stress detection sensor installed at the power end comprises a tension sensor mounted at the pull rod of the fracturing pump, and is configured to detect the stress information in the pull rod by: obtaining end tension information of the pull rod as detected by the tension sensor; anddetermining the stress information of the pull rod based on the end tension information in the pull rod and preset end cross-sectional area information of the pull rod.

10. The fracturing pump operation fault detection system according to claim 8, wherein the pull rod stress detection sensor installed at the power end comprises a strain sensor mounted at the pull rod, and is configured to detect the stress information in the pull rod by: obtaining end strain information of the pull rod as detected by the strain sensor; anddetermining the stress information of the pull rod based on the end strain information in the pull rod, preset elastic modulus information of a material associated with the pull rod, and preset end cross-sectional area information of the pull rod.

11. The fracturing pump operation fault detection system according to claim 8, wherein determining the pump cavity liquid pressure information of the fracturing pump according to the stress information of the pull rod comprises: obtaining piston cross-sectional area information of the fracturing pump associated with the pull rod; andperforming calculation based on the piston cross-sectional area information and the stress information of the pull rod, to obtain the pump cavity liquid pressure information of the fracturing pump.

12. The fracturing pump operation fault detection system according to claim 8, wherein the pump cavity liquid pressure information processing circuitry is configured to determine the operation fault detection result of the fracturing pump according to the pump cavity liquid pressure information and phase information of the plunger by: determining the phase information of the plunger corresponding to the stress information of the pull rod;detecting whether the pump cavity liquid pressure information is consistent with the phase information of the plunger;determining liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the phase information of the plunger if the pump cavity liquid pressure information is consistent with the phase information of the plunger; andgenerating an abnormal detection result for the fracturing pump if the liquid pressure information of the fracturing pump does not meet a preset pressure threshold.

13. The fracturing pump operation fault detection system according to claim 12, wherein the pump cavity liquid pressure information processing circuitry is configured to determine the liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the phase information of the plunger by: if the phase information of the plunger belongs to first phase information of the plunger, determining the liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the first phase information of the plunger; andif the phase information of the plunger belongs to second phase information of the plunger, determining the liquid pressure information of the fracturing pump according to the pump cavity liquid pressure information and the second phase information of the plunger.

14. The fracturing pump operation fault detection system according to claim 13, wherein the pump cavity liquid pressure information processing circuitry is configured to, after generating the abnormal detection result of the fracturing pump: trigger an output of alarm information based on the abnormal detection result, whereinthe pump cavity liquid pressure information processing circuitry is configured to generate the abnormal detection result by: if the liquid pressure information does not meet a preset first pressure information threshold, generating a first detection result indicating that the fracturing pump is abnormal for a first reason; and if the liquid pressure information does not meet a preset second pressure information threshold, generating a second detection result indicating that the fracturing pump is abnormal for a second reason.

15. A fracturing pump operation fault detection device, comprising a processor, a communication interface, a memory, and a communication bus, wherein the processor, the communication interface, and the memory communicate with each other through the communication bus; the memory is configured to store a computer program; andthe processor is configured to implement, when executing the computer program stored in the memory, the fracturing pump operation fault detection method according to claim 1.

16. A non-transitory computer-readable storage medium, having a computer program stored therein, wherein the computer program, when being executed by a processor, implements the fracturing pump operation fault detection method according claim 1.