CN219412530U - Shaft cutting monitoring device - Google Patents

Abstract

The utility model provides a wellbore cutting monitoring device, which comprises: a cutting device for being partially disposed in the wellbore and receiving a cutting material, the cutting material being utilized to cut the wellbore; the detection device is arranged at the part of the cutting device, which is arranged in the shaft, and is used for collecting acoustic wave information in the shaft; the analysis device is arranged outside the shaft and is electrically connected with the detection device, and is used for receiving, analyzing and processing the acoustic wave information and determining the result that the shaft is cut or not cut. According to the utility model, the cutting device cuts the shaft, the detection device collects the acoustic wave information in the shaft, the analysis device analyzes and processes the acoustic wave information, and further, the result that the shaft is cut or not cut is determined, the time when the shaft is cut can be accurately determined, whether the shaft is cut or not is determined through calculating the force value as in the prior art, and the method is simple and convenient.

Description

Shaft cutting monitoring device

Technical Field

The utility model relates to the technical field of underground monitoring, in particular to a wellbore cutting monitoring device.

Background

Disposal of offshore abandoned oil production platforms involves a number of cutting operations, including cutting of abandoned wellbores. Referring to fig. 1, when cutting a abandoned wellbore 2', it is generally required to cut and recover it 3 to 5m below the mud line 1', where the cutting position is indicated by reference numeral 3' in fig. 1. At present, the abrasive jet cutting technology is a high-new technology with the most development potential, and is developing at a high speed in recent years, but when the abrasive jet cutting technology is applied to cutting a shaft below a mud line, the problem is how to judge the cutting timing of the shaft. Since the slits at the time of cutting are small and the friction of the seabed soil acts, it cannot be confirmed whether the cutting is completed by whether the well bore collapses.

In order to perfect the abrasive jet cutting method, following foreign experience, the well bore is usually hoisted by a crane on a platform when cutting is performed, and, referring to fig. 1, the lifting force F of the wire rope must be greater than the sum of the weight G of the well bore itself (the weight above the cutting position 3') and the friction P of the subsea soil. If the wellbore has not been lifted by the lifting force F of the wireline approaching twice the weight G of the wellbore itself, the cut is considered to have not been completed. During this operation the lifting force F cannot exceed twice the weight G of the shaft itself, since the shaft is not completely severed and the cable already provides a large lifting force F, under the effect of which the shaft may be suddenly disconnected, thus presenting a potential hazard. It can be seen from this that the abrasive jet cutting technique defines a narrower range of lifting forces F, namely: f > G+P and F < 2G must be satisfied. However, in actual operation, the calculation of the weight G of the shaft is relatively accurate, but the friction P of the seabed soil to the shaft can only be roughly estimated, so that the wire rope lifting force F is difficult to accurately estimate, and thus whether the shaft is cut cannot be accurately estimated.

Disclosure of Invention

In view of the above, the utility model provides a device for monitoring the cutting of a shaft, which aims to solve the problem that whether the shaft is cut or not can not be accurately estimated in the prior art.

The utility model provides a wellbore cutting monitoring device, which comprises: a cutting device for being partially disposed in the wellbore and receiving a cutting material, the cutting material being utilized to cut the wellbore; the detection device is arranged at the part of the cutting device, which is arranged in the shaft, and is used for collecting acoustic wave information in the shaft; the analysis device is arranged outside the shaft and is electrically connected with the detection device, and is used for receiving, analyzing and processing the acoustic wave information and determining the result that the shaft is cut or not cut.

Further, in the wellbore cutting monitoring device, the detection device includes: the sound wave receiver is arranged at the part of the cutting device, which is arranged in the shaft, and is used for collecting sound wave information in the shaft; the data acquisition device is arranged at the part of the cutting device, which is arranged in the shaft, and is electrically connected with the sound wave receiver, and is used for receiving sound wave information and converting the sound wave information into sound wave electric signals; and the converter is arranged at the part of the cutting device arranged in the shaft and is electrically connected with the data collector and the analysis device, and is used for receiving the acoustic wave electric signal, converting the acoustic wave electric signal into an acoustic wave digital signal and then transmitting the acoustic wave digital signal to the analysis device.

Further, in the wellbore cutting monitoring device, the acoustic information includes: the amplitude and frequency of the sound waves.

Further, in the wellbore cutting monitoring device, at least two detection devices are provided, and each detection device is arranged at a part of the cutting device, which is arranged in the wellbore, at intervals.

Further, in the wellbore cutting monitoring device, the analysis device includes: the digital signal receiving preprocessor is arranged outside the shaft and is electrically connected with the converter, and is used for receiving the sound wave digital signal and calculating each parameter of the sound wave digital signal; the neural network discriminator is arranged outside the shaft and is electrically connected with the digital signal receiving preprocessor, and is used for receiving and processing each parameter of the calculated sound wave digital signal and outputting the result of the shaft being cut or not; the display device is arranged outside the shaft and is electrically connected with the neural network discriminator and is used for receiving and displaying the result that the shaft is cut or not cut.

Further, in the wellbore cutting monitoring device, the neural network discriminator is configured to output a first preset value when the wellbore is cut, and output a second preset value when the wellbore is not cut; the display device is used for displaying the first preset value or the second preset value.

Further, in the wellbore cutting monitoring device, the neural network discriminator is further used for outputting an acoustic curve of the acoustic digital signal; the display device is also used for receiving and displaying the acoustic wave curve of the acoustic wave digital signal.

Further, in the wellbore cutting monitoring device, the analyzing device further includes: and the remote transmission device is electrically connected with the neural network discriminator and is used for receiving and transmitting the result that the shaft is cut or not cut.

In the wellbore cutting monitoring device, the detection device and the analysis device are connected through a shielding cable.

Further, in the wellbore cutting monitoring device, the cutting device includes: the rotary driving device is arranged outside the shaft and is used for receiving the cutting materials; the first end of the oil pipe is connected with the rotary driving device, the oil pipe penetrates through the top of the shaft, and the second end of the oil pipe is arranged in the shaft; the anchoring device is arranged in the shaft and is used for anchoring with the inner wall of the shaft, a rotatable rotating shaft is arranged in the anchoring device, and the first end of the rotating shaft is connected with the second end of the oil pipe; the detection device is arranged on the anchoring device; the cutting head is arranged in the shaft and connected with the second end of the rotating shaft; a plurality of nozzles arranged on the cutting head at intervals; the cutting head is used for receiving the cutting materials conveyed by the oil pipe and the anchoring device and spraying out through each nozzle; the rotary driving device is also used for driving the oil pipe to rotate and driving the rotary shaft and the cutting head to rotate.

According to the utility model, the cutting device cuts the shaft, the detection device collects the acoustic wave information in the shaft, the analysis device analyzes and processes the acoustic wave information, and further, the cutting or non-cutting result of the shaft is determined, the cutting time of the shaft can be accurately determined, whether the shaft is cut or not is determined by calculating the force value as in the prior art, simplicity and convenience are realized, and the problem that whether the shaft is cut or not cannot be accurately estimated in the prior art is solved.

Drawings

Various other advantages and benefits will become apparent to those of ordinary skill in the art upon reading the following detailed description of the preferred embodiments. The drawings are only for purposes of illustrating the preferred embodiments and are not to be construed as limiting the utility model. Also, like reference numerals are used to designate like parts throughout the figures. In the drawings:

FIG. 1 is a schematic diagram of a prior art force analysis of a wellbore;

FIG. 2 is a schematic diagram of a wellbore fracture monitoring apparatus according to an embodiment of the present disclosure;

FIG. 3 is a block diagram of a detection device in a wellbore fracture monitoring device according to an embodiment of the present utility model;

FIG. 4 is a block diagram of an analysis device in a wellbore cut-off monitoring device according to an embodiment of the present utility model;

FIG. 5 is a network configuration diagram of a neural network discriminator in the wellbore cut-off monitoring device provided by the embodiment of the utility model;

FIG. 6 is a graph of acoustic waves for a wellbore sever monitoring apparatus according to an embodiment of the present utility model;

fig. 7 is a diagram showing the error of the neural network discriminator and the training frequency in the wellbore fracture monitoring device according to the embodiment of the utility model.

Detailed Description

Exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. While exemplary embodiments of the present disclosure are shown in the drawings, it should be understood that the present disclosure may be embodied in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the disclosure to those skilled in the art. It should be noted that, without conflict, the embodiments of the present utility model and features of the embodiments may be combined with each other. The utility model will be described in detail below with reference to the drawings in connection with embodiments.

Wellbore cut monitoring device embodiment:

referring to fig. 2, fig. 2 is a schematic structural diagram of a wellbore fracture monitoring device according to an embodiment of the present utility model. As shown, a wellbore cut monitoring device includes: a cutting device 1, a detecting device 2 and an analyzing device 3. Wherein a part of the cutting device 1 is placed inside the wellbore 4 and another part of the cutting device 1 is placed outside the wellbore 4. The cutting device 1 is adapted to receive a cutting material with which a wellbore 4 is cut.

The detection device 2 is arranged at a part of the cutting device 1 arranged in the shaft 4, and the detection device 2 is used for collecting acoustic wave information in the shaft 4, wherein the acoustic wave information comprises: the amplitude and frequency of the sound waves.

The analysis device 3 is arranged outside the wellbore 4, and the analysis device 3 is electrically connected to the detection device 2, in particular, the analysis device 3 is connected to the detection device 2 by a shielded cable 5. The analysis device 3 is configured to receive the acoustic information collected by the detection device 2, analyze the acoustic information, and determine a result that the wellbore 4 is severed or the wellbore 4 is not severed.

It can be seen that in this embodiment, the cutting device 1 cuts the wellbore 4, the detecting device 2 collects the acoustic information in the wellbore 4, the analyzing device 3 analyzes and processes the acoustic information, and further determines the result that the wellbore 4 is cut or not cut, so that the time when the wellbore 4 is cut can be accurately determined, and whether the wellbore 4 is cut or not is determined without calculating the force value as in the prior art, which is simple and convenient, and the problem that whether the wellbore is cut or not cannot be accurately estimated in the prior art is solved.

Referring to fig. 2 and 3, in the above embodiment, the detecting device 2 includes: an acoustic receiver 21, a data collector 22 and a transducer 23. Wherein, the sound wave receiver 21 is arranged at the part of the cutting device 1 arranged in the shaft 4, specifically, the sound wave receiver 21 is arranged in the shaft 4, and the sound wave receiver 21 is used for collecting sound wave information in the shaft 4.

The data collector 22 is disposed in the well bore 4, and the data collector 22 is disposed at a portion of the cutting device 1 disposed in the well bore 4, the data collector 22 is electrically connected with the acoustic receiver 21, and the data collector 22 is configured to receive acoustic information collected by the acoustic receiver 21 and convert the acoustic information into acoustic electrical signals through a "piezoelectric effect".

The transducer 23 is disposed in the wellbore 4, and the transducer 23 is disposed in a portion of the cutting device 1 disposed in the wellbore 4. The converter 23 is electrically connected to the data collector 22 and the analysis device 3, and the converter 23 is configured to receive the acoustic wave electrical signal sent by the data collector 22, convert the acoustic wave electrical signal into an acoustic wave digital signal, and send the acoustic wave digital signal to the analysis device 3. Specifically, the converter 23 is an a/D converter.

Preferably, there are at least two detection devices 2, each detection device 2 cutting the portion of the device 1 disposed in the wellbore 4 at intervals. More preferably, the detection devices 2 are evenly distributed circumferentially over the portion of the cutting device 1 disposed in the wellbore 4.

It can be seen that, in this embodiment, the detection device 2 has a simple structure and is convenient to implement, and the data collector 22 generates an acoustic wave electric signal by using the piezoelectric effect, the converter 23 converts the acoustic wave electric signal into an acoustic wave digital signal, and then the acoustic wave digital signal is sent to the analysis device 3, so that the analysis device 3 can receive and process the signal conveniently.

Referring to fig. 2 and 4, in each of the above embodiments, the analyzing apparatus 3 includes: a digital signal receiving preprocessor 31, a neural network discriminator 32 and a display device 33. The digital signal receiving preprocessor 31 is disposed outside the well bore 4, and the digital signal receiving preprocessor 31 is electrically connected with the converter 23, and the digital signal receiving preprocessor 31 is used for receiving the acoustic digital signal sent by the converter 23 and calculating each parameter of the acoustic digital signal. The digital signal receiving preprocessor 31 is connected with the converter 23 through a shielded cable 5.

The neural network discriminator 32 is disposed outside the well bore 4, and the neural network discriminator 32 is electrically connected with the digital signal receiving preprocessor 31, and the neural network discriminator 32 is configured to receive each parameter of the calculated acoustic digital signal, process each parameter of the acoustic digital signal, and output a result of the well bore 4 being cut or not being cut.

The display device 33 is disposed outside the well bore 4, and the display device 33 is electrically connected to the neural network discriminator 32, and the display device 33 is configured to receive the result of the well bore 4 being cut or not being cut, and display the result of the well bore 4 being cut or not being cut.

Specifically, the neural network discriminator 32 is configured to output a first preset value when the wellbore 4 is severed and to output a second preset value when the wellbore 4 is not severed. The display device 33 is configured to receive the first preset value or the second preset value, and display the first preset value or the second preset value.

In specific implementation, the first preset value and the second preset value may be determined according to actual situations, which is not limited in this embodiment. In this embodiment, the first preset value is 0.9, and the second preset value is 0.4.

Preferably, the neural network discriminator 32 is further configured to output an acoustic wave profile of the acoustic wave digital signal, and the display device 33 is further configured to receive and display the acoustic wave profile of the acoustic wave digital signal, and the acoustic wave profile may be referred to in fig. 6. Thus, the display device 33 displays the acoustic wave curve for the convenience of the operator.

Preferably, the neural network discriminator 32 is configured to output a first preset value when the wellbore 4 is severed, and to output a second preset value when the wellbore 4 is not severed; the display device 33 is used for displaying the first preset value or the second preset value; and/or the neural network discriminator 32 is also configured to output a sonic profile of the sonic digital signal; the display device 33 is further configured to receive and display the acoustic wave curve of the acoustic digital signal.

In specific implementation, the detection device 2 collects the amplitude and frequency of the sound wave pressure in the shaft, and can set high-precision sampling frequency before the well is down, so that high-fidelity data receiving of acoustic signals generated by underground cutting is realized. The digital signal receiving preprocessor 31 is a preprocessor of the neural network discriminator 32, and calculates an average value x1, a mean square error x2, a kurtosis x3, and a slope x4 of the acoustic digital signal, thereby generating input data of the neural network discriminator 32. The neural network discriminator 32 receives the data calculated by the digital signal receiving preprocessor 31, outputs a discrimination result of whether the well bore is cut, outputs 0.9 when the well bore is not cut, and outputs 0.4 after the well bore is cut. The neural network discriminator 32 is a three-layer BP network (see fig. 5), in this embodiment, the number of neurons in the input layer is 4, the number of neurons in the output layer is 1, and the number of neurons in the hidden layer may be 7, i.e., the network structure is (4,7,1).

The well bore cutting monitoring device needs to carry out a plurality of indoor calibration simulation experiments before entering a construction site for application so as to train and test the neural network, the training of the neural network is a self-adaptive process, false alarms and false alarms can be generated in the process, but with the increase of test times, a model knowledge base is gradually enriched, and the accuracy is higher and higher.

It can be seen that in this embodiment, the analysis device 3 calculates each parameter of the acoustic digital signal through the digital signal receiving preprocessor 31, the neural network discriminator 32 processes each parameter of the acoustic digital signal by using the neural network structure, and outputs the result of the well bore 4 being cut or not being cut, so that the structure is simple, the accuracy of the result of whether the well bore 4 is cut can be ensured, and the operator can check the result conveniently.

In each of the above embodiments, the analyzing apparatus 3 may further include: a remote transmission device. The remote transmission device is disposed outside the shaft 4 and electrically connected to the neural network discriminator 32, and is configured to receive the result of the shaft 4 being cut or not being cut output by the neural network discriminator 32 and transmit the result of the shaft 4 being cut or not being cut. Thus, even if the distance of the working personnel is far, the working personnel can accurately and timely know the result that the shaft 4 is cut or not cut, and the next operation is convenient.

Referring to fig. 1, in the above embodiments, a cutting device 1 includes: a rotary drive 11, an oil pipe 12, an anchoring device 13, a cutting head 14 and a plurality of nozzles 15. Wherein the rotary driving device 11 is arranged outside the shaft 4, and the rotary driving device 11 is used for receiving the cutting materials. A first end (upper end shown in fig. 2) of the tubing 12 is connected to the rotary drive device 11, the tubing 12 is threaded into the top (upper portion shown in fig. 2) of the wellbore 4, and a second end (lower end shown in fig. 2) of the tubing 12 is disposed inside the wellbore 4.

An anchoring device 13 is arranged in the wellbore 4, the anchoring device 13 being arranged to anchor with the inner wall of the wellbore 4 such that the anchoring device 13 is relatively fixed with respect to the inner wall of the wellbore 4. And, a rotatable shaft (not shown) is provided in the anchoring device 13, a first end of the shaft being connected to a second end of the oil pipe 12. The cutting head 14 is disposed within the wellbore 4 and a second end of the rotary shaft is connected to the cutting head 14. Specifically, the rotation shaft is freely rotatable within the anchoring device 13.

The nozzles 15 are provided at intervals in the cutting head 14, and preferably, the nozzles 15 are uniformly provided in the circumferential direction of the cutting head 14. Specifically, the inside of the cutting head 14 is hollow, the cutting head 14 is provided with a plurality of openings, each nozzle 15 corresponds to each opening one by one, each nozzle 15 is arranged at the corresponding opening, and each opening is uniformly arranged along the circumferential direction of the cutting head 14.

The cutting head 14 is adapted to receive the cutting material delivered via the oil pipe 12 and the anchoring device 13 and to eject it through the respective nozzles 15. Specifically, the interior of the rotary shaft is hollow, the interior of the rotary shaft communicates with the interior of the oil pipe 12, and the interior of the rotary shaft communicates with the interior of the cutting head 14. The cutting material is conveyed into the oil pipe 12 through the rotary driving device 11, then conveyed into the interior of the rotary shaft and the cutting head 14 after being output from the oil pipe 12, finally ejected through the nozzles 15, and the cutting material acts on the inner wall of the shaft 4, so that the shaft 4 is cut.

The rotation driving device 11 is further used for driving the oil pipe 12 to rotate, and since the oil pipe 12 is connected with the cutting head 14 through a rotation shaft, the rotation of the oil pipe 12 drives the rotation of the rotation shaft, and further drives the cutting head 14 to rotate.

The detection means 2 are arranged at the anchoring means 13, in particular the detection means 2 are preferably arranged closer to the cutting head 14, but not in the vicinity of the cutting nozzle 15, in order to avoid damage to the nozzle 15 by the high-speed jet formed by the nozzle.

When there are at least two detection devices 2, each detection device 2 is uniformly disposed along the circumferential direction of the anchor device 13.

In the specific implementation, the structures of the rotary driving device 11, the oil pipe 12, the anchoring device 13, the cutting head 14 and the nozzles 15 in the cutting device 1 may refer to the specific description of the structure of the cutting device in the abrasive jet cutting technology in the prior art, and the description of this embodiment is omitted herein.

It can be seen that in this embodiment, the cutting device 1 has a simple structure and is easy to implement.

The use of the wellbore sever monitoring device will be described with reference to fig. 2:

(1) And training, namely performing a plurality of calibration simulation experiments on the analysis device in the wellbore cutting monitoring device, and stopping the calibration simulation experiments when the output error of the analysis device is smaller than the preset error.

Specifically, a plurality of calibration simulation experiments are performed on the analysis device 3 indoors.

Before the construction site is applied, each part in the shaft cutting monitoring device is installed indoors, and a plurality of calibration simulation experiments are carried out under the same working condition as the actual application until the output error of the analysis device is smaller than the preset error, and then training is completed. In specific implementation, the preset error may be determined according to practical situations, which is not limited in this embodiment.

In this embodiment, referring to fig. 7, after 26 calibration simulation experiments, the output error of the analysis device is smaller than the preset error. In this embodiment, the neural network arbiter 32 is trained using the Levenberg-Marquardt optimization method, the error sum of squares index is set to 0.005, and the minimum gradient is set to 0.0001.

(2) And a mounting step of mounting the cutting device 1 in the wellbore cutting monitoring device to the wellbore 4 and mounting the detection device 2 to a portion of the cutting device 1 disposed in the wellbore 4.

Specifically, a wellbore severance monitoring device is installed to a wellbore at a construction site. The rotary driving device 11 is arranged outside the shaft 4, a first end of the oil pipe 12 is connected with the rotary driving device 11, the oil pipe 12 penetrates through the top of the shaft 4, and a second end of the oil pipe 12 is arranged inside the shaft 4 and connected with a first end of a rotary shaft in the anchoring device 13. The anchoring device 13 is anchored to the inner wall of the wellbore 4 and the second end of the rotary shaft is connected to the cutting head 14. The detection means 2 are arranged at the anchoring means 13.

(3) And in the water injection step, starting the cutting device 1, conveying clear water into the shaft 4 through the cutting device 1, and starting the detection device 2, wherein the detection device 2 collects acoustic wave information in the shaft 4.

Specifically, the rotary driving device 11 in the cutting device 1 is started, the rotary driving device 11 drives the oil pipe 12 to rotate, and the rotation of the oil pipe 12 drives the rotation of the rotary shaft and further drives the cutting head 14 to rotate. The detection device 2 is started at the same time as the cutting device 1 is started, and the detection device 2 acquires acoustic information in the well bore 4 in real time.

The fracturing truck delivers high-pressure clean water to the rotary driving device 11, the rotary driving device 11 delivers high-pressure clean water to the oil pipe 12, the high-pressure clean water is delivered from the oil pipe 12 and then sequentially delivered to the rotary shaft and the cutting head 14, and finally the high-pressure clean water is sprayed into the shaft 4 through the nozzles 15.

(4) And a cutting step, namely conveying cutting materials into the shaft 4 through the cutting device 1 after conveying clear water to a preset time, and cutting the shaft 4 by the cutting materials.

Specifically, the preset time is 2-5 min. Of course, the preset time may also be determined according to the actual situation, which is not limited in this embodiment.

After the high-pressure clean water is conveyed for 2-5 min, starting a sand mixing device, mixing abrasive particles with the high-pressure clean water by the sand mixing device to form high-pressure abrasive slurry, wherein the high-pressure abrasive slurry is a cutting material, and is conveyed into a rotary driving device 11 through a fracturing truck to be conveyed into an oil pipe 12, then conveyed into a rotary shaft and a cutting head 14 in sequence after being output from the oil pipe 12, finally high-speed abrasive jet flow is formed to be sprayed out through each nozzle 15, and the well bore 4 is cut.

During the process of cutting the well bore 4 by the cutting material, the detection device 2 acquires acoustic information in the well bore 4 in real time.

(5) And stopping the step of analyzing and processing the acoustic wave information, and stopping conveying the cutting material when the well bore 4 is determined to be cut.

Specifically, the analysis device 3 is disposed outside the wellbore 4, and the digital signal receiving pre-processor 31 is electrically connected to the transducer 23, and the digital signal receiving pre-processor 31 receives the acoustic digital signal sent by the transducer 23 and calculates each parameter of the acoustic digital signal. The neural network discriminator 32 processes the parameters of the acoustic digital signal and outputs the result of the wellbore 4 being severed or not severed. Specifically, a first preset value is output when the wellbore 4 is severed, and a second preset value is output when the wellbore 4 is not severed. The display device 33 receives and displays the result of the wellbore 4 being severed or not severed, in particular, the first preset value or the second preset value. In this embodiment, the first preset value is 0.9, and the second preset value is 0.4.

Referring to fig. 1, a wellbore 4 includes: an inner casing 41, a cementing cement sheath 42, and an outer casing 43; the outer casing 43 is sleeved outside the inner casing 41, and a preset gap is formed between the outer casing 43 and the inner casing 41, and a well cementing cement ring 42 is arranged in the gap.

When the high-speed abrasive jet is sprayed out of each nozzle 15 and then cuts the shaft 4, the inner sleeve 41 is cut first, the sound wave fed back after the high-speed abrasive jet impacts the inner sleeve 41 is received by the detection device 2, the sound wave fed back after the jet impacts the inner sleeve 41 is reflected to be different from the sound wave form in the initial cutting along with the gradual deepening of the cutting depth, and after the inner sleeve 41 is completely cut off, the high-speed abrasive jet cuts the well cementation cement ring 42, and the materials of the well cementation cement ring 42 and the sleeve are different, so that the sound wave form (amplitude, frequency, sound intensity and the like) fed back by the high-speed abrasive jet is completely different from the previous sound wave form.

Referring to fig. 6, the acoustic wave of jet cutting feedback is shown divided into A, B, C three stages, the cutting process is:

(1) And A phase: the clear water is cut for 0-200 seconds, abrasive particles are not arranged in the jet flow, the clear water jet flow impacts the inner sleeve 41 (made of metal), the acoustic wave curve integrally shows a horizontal trend, and the amplitude is larger. The output value from the analysis device 3 was 0.9, indicating that it was not severed.

(2) B, stage: 200-600 seconds, the sand mixing device is started, the clear water jet becomes abrasive jet, the inner sleeve 41 starts to be cut, the amplitude is further increased, and the sound pressure level is slowly reduced along with the gradual increase of the cutting depth. The output value of the analysis means 3 decreases stepwise, indicating that the sleeve is being severed.

(3) And C, stage: after 600 seconds, the abrasive jet has completely severed the inner casing 41, cutting of the solid cement sheath 42 begins, the sound pressure level fluctuates due to the heterogeneity of the solid cement sheath 42, but the overall trend is smoother, and the sound pressure level in stage C is overall less than that in stages a and B. The output value of the analysis device 3 was 0.4, indicating that the sleeve was severed.

Since the outer casing 43 is farther from the inner casing 41, the high velocity abrasive jet will take longer to reach the outer casing 43, and thus the sonic profile of the jet cutting the outer casing 43 is not shown in fig. 6 of this embodiment, but does not affect the determination of a fracture of the wellbore 4.

After the outer casing 43 of the wellbore 4 is also severed, the delivery of cuttings is stopped.

In practice, the installation step, the water injection step, the cutting step and the stopping step are all performed at the construction site.

In summary, in this embodiment, a multiple calibration simulation experiment is performed on an analysis device in a shaft cutting monitoring device, so as to ensure that an output error of the analysis device is smaller than a preset error, further ensure accuracy of analysis of the analysis device, then convey cutting materials into a cutting device to cut the shaft, collect acoustic wave information in the shaft in real time by a detection device in a cutting process, analyze and process the acoustic wave information, and stop conveying the cutting materials when determining that the shaft is cut, where the device uses a sound wave difference fed back when cutting targets made of different materials by abrasive jet as a judgment principle, so that a time when the shaft is cut can be accurately determined, and whether the shaft is cut or not is determined by a calculation force value as in the prior art is not required.

It should be noted that, in the description of the present utility model, terms such as "upper," "lower," "left," "right," "inner," "outer," and the like indicate directions or positional relationships based on the directions or positional relationships shown in the drawings, which are merely for convenience of description, and do not indicate or imply that the apparatus or elements must have a specific orientation, be constructed and operated in a specific orientation, and thus should not be construed as limiting the present utility model.

Furthermore, it should be noted that, in the description of the present utility model, unless explicitly specified and limited otherwise, the terms "mounted," "connected," and "connected" are to be construed broadly, and may be either fixedly connected, detachably connected, or integrally connected, for example; can be directly connected or indirectly connected through an intermediate medium, and can be communication between two elements. The specific meaning of the above terms in the present utility model can be understood by those skilled in the art according to the specific circumstances.

It will be apparent to those skilled in the art that various modifications and variations can be made to the present utility model without departing from the spirit or scope of the utility model. Thus, it is intended that the present utility model also include such modifications and alterations insofar as they come within the scope of the appended claims or the equivalents thereof.

Claims (10)

1. A wellbore severance monitoring device, comprising:

-a cutting device (1) for being placed partly in a wellbore (4) and receiving a cutting charge with which the wellbore (4) is cut;

the detection device (2) is arranged at the part of the cutting device (1) arranged in the shaft (4) and is used for collecting acoustic wave information in the shaft (4);

the analysis device (3) is arranged outside the shaft (4) and is electrically connected with the detection device (2) and is used for receiving, analyzing and processing the acoustic wave information and determining the result that the shaft (4) is cut or not cut.

2. The wellbore severance monitoring device according to claim 1, wherein the detection device (2) comprises:

the sound wave receiver (21) is arranged at the part of the cutting device (1) arranged in the shaft (4) and is used for collecting sound wave information in the shaft (4);

the data acquisition device (22) is arranged at the part of the cutting device (1) arranged in the shaft (4) and is electrically connected with the sound wave receiver (21) and is used for receiving the sound wave information and converting the sound wave information into sound wave electric signals;

the converter (23) is arranged at the part of the cutting device (1) arranged in the shaft (4) and is electrically connected with the data collector (22) and the analysis device (3), and is used for receiving the acoustic wave electric signals, converting the acoustic wave electric signals into acoustic wave digital signals and then transmitting the acoustic wave digital signals to the analysis device (3).

3. The wellbore severance monitoring device of claim 2 wherein the acoustic message comprises: the amplitude and frequency of the sound waves.

4. The wellbore severance monitoring device according to claim 2, wherein there are at least two detection devices (2), each detection device (2) being arranged at a distance from a portion of the cutting device (1) arranged in the wellbore (4).

5. The wellbore severance monitoring device according to claim 2, wherein the analysis device (3) comprises:

a digital signal receiving preprocessor (31) which is arranged outside the shaft (4) and is electrically connected with the converter (23) and is used for receiving the sound wave digital signal and calculating each parameter of the sound wave digital signal;

the neural network discriminator (32) is arranged outside the shaft (4) and is electrically connected with the digital signal receiving preprocessor (31) and is used for receiving and processing each calculated parameter of the sound wave digital signal and outputting the result of the shaft (4) being cut or not;

and the display device (33) is arranged outside the shaft (4) and is electrically connected with the neural network discriminator (32) and is used for receiving and displaying the result of the cutting or non-cutting of the shaft (4).

6. The wellbore severance monitoring device of claim 5 wherein,

the neural network discriminator (32) is used for outputting a first preset value when the shaft (4) is cut off, and outputting a second preset value when the shaft (4) is not cut off;

the display device (33) is used for displaying the first preset value or the second preset value.

7. The wellbore severance monitoring device of claim 5 wherein,

the neural network discriminator (32) is also used for outputting an acoustic curve of the acoustic digital signal;

the display device (33) is also used for receiving and displaying the acoustic wave curve of the acoustic wave digital signal.

8. The wellbore severance monitoring device according to claim 5, wherein the analysis device (3) further comprises:

and the remote transmission device is electrically connected with the neural network discriminator (32) and is used for receiving and transmitting the result that the shaft (4) is cut or not cut.

9. The wellbore severance monitoring device according to claim 4, characterized in that the detection device (2) and the analysis device (3) are connected by a shielded cable.

10. The wellbore severance monitoring device according to claim 1, wherein the cutting device (1) comprises:

the rotary driving device (11) is arranged outside the shaft (4) and is used for receiving cutting materials;

the first end of the oil pipe (12) is connected with the rotary driving device (11), the oil pipe (12) penetrates through the top of the shaft (4) and the second end of the oil pipe is arranged in the shaft (4);

an anchoring device (13) arranged in the shaft (4) and used for anchoring with the inner wall of the shaft (4), wherein a rotatable rotating shaft is arranged in the anchoring device (13), and the first end of the rotating shaft is connected with the second end of the oil pipe (12); the detection device (2) is arranged on the anchoring device (13);

a cutting head (14) disposed within the wellbore (4) and connected to the second end of the rotating shaft;

a plurality of nozzles (15) provided at intervals to the cutting head (14);

the cutting head (14) is used for receiving the cutting materials conveyed through the oil pipe (12) and the anchoring device (13) and spraying out through each nozzle (15);

the rotary driving device (11) is also used for driving the oil pipe (12) to rotate and driving the rotary shaft and the cutting head (14) to rotate.