Pump stroke noise suppression method and device

Abstract

The invention provides a pump stroke noise suppression method and device, and the method comprises the steps: obtaining an estimated pump stroke harmonic frequency, a theoretical coding signal frequency and an original pressure wave signal, and carrying out the primary denoising processing, and obtaining a pressure wave signal after the primary denoising; performing frequency spectrum correction processing on the pressure wave signal after primary denoising to obtain a target pump stroke harmonic amplitude, a target pump stroke harmonic frequency and a target pump stroke harmonic phase, and performing target pump stroke harmonic noise reconstruction; subtracting the target pump stroke harmonic noise from the pressure wave signal after primary denoising to obtain a pressure wave signal after secondary denoising; and determining underground measurement data according to the pressure wave signal subjected to secondary denoising. Relevant information of a pump stroke harmonic signal is obtained from a riser pressure wave signal, and the related information is reconstructed, so that effective extraction of coded pulses is realized, and field requirements of complex recent conditions are met.

Description

Technical Field

[0001] The invention relates to the technical field of drilling engineering in oil and gas exploration and development, and in particular to a method and device for suppressing pump impulse noise. Background Art

[0002] Mud pulse transmission is a data transmission method commonly used in the current oil drilling process. It can provide various downhole parameters to the well site personnel in real time, such as well inclination, azimuth and tool face, etc. The principle is that the downhole instrument changes the mud pressure in the drill string through the pulse generator, forming a pressure wave and transmitting the measurement data to the ground in the form of pulses.

[0003] When mud pulse signals propagate in the drill pipe, they will inevitably be interfered by various noises. The pump impulse interference generated by the mud pump is one of the important factors affecting the communication quality (especially when the frequencies of the coded signal and the pump impulse noise are similar). Eliminating the pump impulse interference is crucial for subsequent signal decoding.

[0004] Since the movement of the mud pump has good periodicity in most cases, the pump impulse noise usually appears as a harmonic signal in the pressure waveform collected by the standpipe pressure sensor. Therefore, the pump impulse noise can be suppressed by using the amplitude, frequency and phase information of the pump impulse harmonic signal. The existing pump impulse noise suppression methods mainly include: bandpass filtering, notch filtering, wavelet transform, modal decomposition and adaptive filtering. However, these methods usually do not take into account the slight fluctuations of the pump impulse frequency, which may lead to poor denoising effect of the algorithm in some cases. Summary of the invention

[0005] The present invention provides a method and device for suppressing pump impulse noise, which obtains relevant information of pump impulse harmonic signals from standpipe pressure wave signals and reconstructs the relevant information, thereby achieving effective extraction of coded pulses and meeting on-site needs of complex situations.

[0006] In a first aspect, the present invention provides a method for suppressing pump impulse noise, comprising:

[0007] Acquire an estimated pump stroke harmonic frequency, a theoretical coding signal frequency, and an original pressure wave signal, and perform a denoising process on the original pressure wave signal based on the estimated pump stroke harmonic frequency and the theoretical coding signal frequency to obtain a denoised pressure wave signal;

[0008] Performing spectrum correction processing on the pressure wave signal after the primary denoising to obtain a target pump stroke harmonic amplitude, a target pump stroke harmonic frequency and a target pump stroke harmonic phase;

[0009] reconstructing a target pump stroke harmonic noise based on the target pump stroke harmonic amplitude, the target pump stroke harmonic frequency, and the target pump stroke harmonic phase;

[0010] Subtracting the target pump stroke harmonic noise from the primary denoised pressure wave signal to obtain a secondary denoised pressure wave signal;

[0011] The downhole measurement data is determined according to the secondary denoised pressure wave signal.

[0012] Optionally, obtaining downhole measurement data according to the secondary denoised pressure wave signal includes:

[0013] Combining the secondary denoised pressure wave signal with the previously processed historical secondary denoised pressure wave signal to obtain a pressure wave signal to be decoded;

[0014] The pressure wave signal to be decoded is decoded to obtain the downhole measurement data.

[0015] Optionally, obtaining an estimated pump stroke harmonic frequency, a theoretical coding signal frequency, and an original pressure wave signal, and performing a denoising process on the original pressure wave signal based on the estimated pump stroke harmonic frequency and the theoretical coding signal frequency to obtain a denoised pressure wave signal, including:

[0016] Determine the estimated pump stroke harmonic frequency based on the obtained pump stroke rate, the number of pump cylinders and the pump action mode;

[0017] Based on the acquired theoretical coded signal frequency and the estimated pump stroke harmonic frequency, acquiring a target pressure wave signal frequency range;

[0018] Based on the target pressure wave signal frequency range, the original pressure wave signal is subjected to a denoising process to obtain a denoised pressure wave signal.

[0019] Optionally, based on the obtained pump stroke rate, the number of pump cylinders and the pump action mode, an estimated pump stroke harmonic frequency is determined, including:

[0020] Based on the number of cylinders of the pump and the action mode of the pump, combined with a preset main control harmonic order calculation expression, the order of the main control harmonic is determined;

[0021] Based on the order of the main control harmonic and the pump stroke rate, in combination with a preset pump stroke harmonic frequency calculation expression, the pump stroke harmonic frequency at the main control harmonic order is determined.

[0022] Optionally, the master control harmonic order calculation expression is:

[0023] n=m×N c ×a;

[0024] The pump stroke harmonic frequency calculation expression is:

[0025]

[0026] Among them, n is the number of main control harmonics; m is a positive integer; N c is the number of cylinders of the pump; a is the working mode, single-acting a is 1, double-acting a is 2, f n is the frequency of the nth harmonic; S is the pump stroke rate, that is, the number of pump strokes per minute.

[0027] In a second aspect, the present invention provides a drilling pump noise suppression device, comprising:

[0028] An acquisition module, used to acquire an estimated pump stroke harmonic frequency, a theoretical coding signal frequency and an original pressure wave signal, and perform a denoising process on the original pressure wave signal based on the estimated pump stroke harmonic frequency and the theoretical coding signal frequency to obtain a denoised pressure wave signal;

[0029] A correction module, used for performing spectrum correction processing on the pressure wave signal after the primary denoising to obtain a target pump stroke harmonic amplitude, a target pump stroke harmonic frequency and a target pump stroke harmonic phase;

[0030] A reconstruction module, configured to reconstruct a target pump stroke harmonic noise based on the target pump stroke harmonic amplitude, the target pump stroke harmonic frequency and the target pump stroke harmonic phase;

[0031] A secondary denoising module, used for subtracting the target pump impulse harmonic noise from the pressure wave signal after the primary denoising to obtain the pressure wave signal after the secondary denoising;

[0032] The downhole measurement data determination module is used to determine the downhole measurement data according to the pressure wave signal after the secondary denoising.

[0033] Optionally, the downhole measurement data determination module includes:

[0034] A pressure wave signal to be decoded determination submodule, used for combining the secondary denoised pressure wave signal with the previously processed historical secondary denoised pressure wave signal to obtain a pressure wave signal to be decoded;

[0035] The decoding submodule is used to decode the pressure wave signal to be decoded to obtain the downhole measurement data.

[0036] Optionally, the acquisition module includes:

[0037] An estimated pump stroke harmonic frequency determination submodule, used to determine the estimated pump stroke harmonic frequency based on the acquired pump stroke rate, the number of pump cylinders and the pump action mode;

[0038] A target pressure wave signal frequency range determination submodule, used to obtain a target pressure wave signal frequency range based on the acquired theoretical coded signal frequency and the estimated pump stroke harmonic frequency;

[0039] The primary denoising submodule is used to perform a primary denoising process on the original pressure wave signal based on the target pressure wave signal frequency range to obtain a primary denoised pressure wave signal.

[0040] In a third aspect, the present application provides an electronic device, comprising a processor and a memory, wherein the memory stores computer-readable instructions, and when the computer-readable instructions are executed by the processor, the steps in the method provided in the first aspect are performed.

[0041] In a fourth aspect, the present application provides a storage medium having a computer program stored thereon, wherein when the computer program is executed by a processor, the steps in the method provided in the first aspect are performed.

[0042] It can be seen from the above technical solutions that the present invention has the following advantages:

[0043] The present invention provides a method and device for suppressing pump impulse noise, the method comprising: obtaining an estimated pump impulse harmonic frequency, a theoretical coding signal frequency and an original pressure wave signal, and performing a primary denoising process on the original pressure wave signal based on the estimated pump impulse harmonic frequency and the theoretical coding signal frequency to obtain a primary denoised pressure wave signal; performing spectrum correction process on the primary denoised pressure wave signal to obtain a target pump impulse harmonic amplitude, a target pump impulse harmonic frequency and a target pump impulse harmonic phase; reconstructing a target pump impulse harmonic noise based on the target pump impulse harmonic amplitude, the target pump impulse harmonic frequency and the target pump impulse harmonic phase; subtracting the target pump impulse harmonic noise from the primary denoised pressure wave signal to obtain a secondary denoised pressure wave signal; determining downhole measurement data based on the secondary denoised pressure wave signal. By obtaining relevant information of the pump impulse harmonic signal from the riser pressure wave signal and reconstructing the relevant information, effective extraction of coded pulses is achieved to meet the on-site needs of complex current conditions. BRIEF DESCRIPTION OF THE DRAWINGS

[0044] In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings required for use in the embodiments or the description of the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative labor.

[0045] Figure 1 This is a flow chart of a first embodiment of a method for suppressing pump noise according to the present invention;

[0046] Figure 2 It is a schematic structural diagram of the pump impulse interference removal device of the present invention;

[0047] Figure 3 This is a flow chart of a second embodiment of a method for suppressing pump noise according to the present invention;

[0048] Figure 4 is the time domain waveform of the original pressure wave signal;

[0049] Figure 5 is the spectrum of the original pressure wave signal;

[0050] Figure 6 is the time domain waveform of the pressure wave signal after primary denoising;

[0051] Figure 7 is the amplitude spectrum of the pressure wave signal after primary denoising;

[0052] Figure 8 is the amplitude spectrum of the pressure wave signal after spectrum correction;

[0053] Fig. 9 is the time domain waveform of the pressure wave signal after secondary denoising;

[0054] Fig.10 Schematic diagram of the amplitude spectrum of the pressure wave signal after secondary denoising;

[0055] Fig.11 The present invention is a structural block diagram of an embodiment of suppressing pump impulse noise. DETAILED DESCRIPTION

[0056] The embodiment of the present invention provides a method and device for suppressing pump impulse noise, which obtains relevant information of the pump impulse harmonic signal from the riser pressure wave signal and reconstructs the relevant information, thereby realizing effective extraction of coded pulses and meeting the on-site needs of complex current conditions.

[0057] In order to make the purpose, features and advantages of the present invention more obvious and easy to understand, the technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the embodiments described below are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the present invention.

[0058] For example, see Figure 1 , Figure 1 The present invention is a process flow chart of a first embodiment of a method for suppressing pump impulse noise, comprising:

[0059] Step S101, obtaining an estimated pump stroke harmonic frequency, a theoretical coding signal frequency and an original pressure wave signal, and performing a denoising process on the original pressure wave signal based on the estimated pump stroke harmonic frequency and the theoretical coding signal frequency to obtain a denoised pressure wave signal;

[0060] In an optional embodiment, an estimated pump stroke harmonic frequency, a theoretical coding signal frequency, and an original pressure wave signal are obtained, and a denoising process is performed on the original pressure wave signal based on the estimated pump stroke harmonic frequency and the theoretical coding signal frequency to obtain a denoised pressure wave signal, including:

[0061] Determine the estimated pump stroke harmonic frequency based on the obtained pump stroke rate, the number of pump cylinders and the pump action mode;

[0062] Based on the acquired theoretical coded signal frequency and the estimated pump stroke harmonic frequency, acquiring a target pressure wave signal frequency range;

[0063] Based on the target pressure wave signal frequency range, the original pressure wave signal is subjected to a denoising process to obtain a denoised pressure wave signal.

[0064] The method in the embodiment of the present invention is applied to Figure 2 The schematic diagram of the pump impulse interference removal device shown in the figure includes: a standpipe pressure sensor 10, a ground interface box 20 and a ground computer 30. The standpipe pressure sensor 10 is installed on the standpipe pressure line to sense the mud pulse pressure wave signal. The ground interface box 20 is used to collect the mud pulse pressure wave signal and transmit it to the ground computer 30. The ground computer 30 is used to process the collected signal and restore it to obtain downhole measurement data.

[0065] In the specific implementation, the primary denoising processing method mainly includes bandpass filtering, wavelet transform and modal decomposition.

[0066] Step S102, performing spectrum correction processing on the pressure wave signal after the primary denoising to obtain a target pump stroke harmonic amplitude, a target pump stroke harmonic frequency and a target pump stroke harmonic phase;

[0067] In the embodiment of the present invention, the spectrum correction processing method mainly includes: interpolation method, phase difference method and energy centroid method.

[0068] Step S103, reconstructing a target pump stroke harmonic noise based on the target pump stroke harmonic amplitude, the target pump stroke harmonic frequency and the target pump stroke harmonic phase;

[0069] Step S104, subtracting the target pump stroke harmonic noise from the primary denoised pressure wave signal to obtain a secondary denoised pressure wave signal;

[0070] Step S105, determining downhole measurement data according to the secondary denoised pressure wave signal.

[0071] A method for suppressing pump impulse noise provided in an embodiment of the present invention includes: obtaining an estimated pump impulse harmonic frequency, a theoretical coding signal frequency and an original pressure wave signal, and performing a denoising process on the original pressure wave signal based on the estimated pump impulse harmonic frequency and the theoretical coding signal frequency to obtain a pressure wave signal after the denoising process; performing spectrum correction process on the pressure wave signal after the denoising process to obtain a target pump impulse harmonic amplitude, a target pump impulse harmonic frequency and a target pump impulse harmonic phase; reconstructing a target pump impulse harmonic noise based on the target pump impulse harmonic amplitude, the target pump impulse harmonic frequency and the target pump impulse harmonic phase; subtracting the target pump impulse harmonic noise from the pressure wave signal after the denoising process to obtain a pressure wave signal after the denoising process; and determining downhole measurement data based on the pressure wave signal after the denoising process. By obtaining relevant information of the pump impulse harmonic signal from the riser pressure wave signal and reconstructing the relevant information, effective extraction of the coded pulse can be achieved to meet the on-site needs of complex current conditions.

[0072] For example 2, please refer to Figure 3 , Figure 3 This is a flow chart of a second embodiment of a method for suppressing pump noise according to the present invention, comprising:

[0073] Step S201, based on the number of cylinders of the pump and the pump action mode, combined with a preset main control harmonic order calculation expression, determine the order of the main control harmonic;

[0074] Step S202, based on the order of the main control harmonic and the pump impulse rate, combined with a preset pump impulse harmonic frequency calculation expression, determine the pump impulse harmonic frequency at the main control harmonic order;

[0075] Specifically, the master control harmonic order calculation expression is:

[0076] n=m×N c ×a;

[0077] The pump stroke harmonic frequency calculation expression is:

[0078]

[0079] Among them, n is the number of main control harmonics; m is a positive integer; N c is the number of cylinders of the pump; a is the working mode, single-acting a is 1, double-acting a is 2, f n is the frequency of the nth harmonic; S is the pump stroke rate, that is, the number of pump strokes per minute.

[0080] It should be noted that in the mud pulse signal, the interference noise mainly includes pump noise, low-frequency baseline noise and random noise. The original mud pulse signal detected by the standpipe pressure sensor can be approximately expressed as:

[0081] s(t)=f(t)+p(t)+m(t)+n(t);

[0082] The pump noise signal can be approximately expressed as:

[0083]

[0084] Among them, s(t) is the original mud pulse signal, f(t) is the coded signal that can be used for subsequent analysis and processing, p(t) is the pump noise signal, m(t) is the low-frequency baseline noise signal, n(t) is the Gaussian random noise signal, and f 0 is the fundamental frequency of the pump impulse, n is the harmonic number, a n is the amplitude of the nth harmonic, is the initial phase of the nth harmonic.

[0085] In the embodiment of the present invention, assuming that the pump stroke rate of the mud pump is 144rpm, the number of cylinders of the pump is 3, and the pump action mode is double-acting, the calculated pump stroke harmonic frequency is 4.8Hz. The 1st, 3rd, 6th, and 9th harmonics (frequencies 4.8Hz, 14.4Hz, 28.8Hz, and 43.2Hz) are the main control harmonics and have higher energy; the energy of other harmonics is relatively weak. If there is a certain error in the pump stroke rate of the drilling pump, for example, 142rpm, the calculated frequencies of the 1st, 3rd, 6th, and 9th harmonics are 4.7333Hz, 14.2Hz, 28.4Hz, and 42.6Hz, respectively, and there is a large difference between the estimated value and the true value. Therefore, the pump stroke frequency obtained by the pump stroke rate calculation has poor accuracy and can only be used as a reference, and cannot be directly used for the processing of pressure wave signals.

[0086] In addition, although the pump impulse interference removal method based on the empirical pump impulse waveform can better meet the needs of the site, this method relies on the rapid and accurate acquisition of the pump impulse harmonic frequency. The traditional pump impulse harmonic frequency acquisition methods mainly include: (1) obtaining the pump impulse signal collected by the pump impulse sensor; (2) obtaining the pump impulse rate calculated by the pump impulse counter. Although the pump impulse frequency obtained by method (1) is very accurate, the site conditions often make it impossible to install a pump impulse sensor, which limits the use of this method. The pump impulse frequency obtained by method (2) is not accurate, which will greatly affect the denoising effect.

[0087] Based on this, the spectrum correction technology is used to quickly and accurately determine the estimated pump stroke harmonic frequency based on the pressure wave signal collected by the riser pressure sensor.

[0088] Step S203, obtaining a target pressure wave signal frequency range based on the obtained theoretical coding signal frequency and the estimated pump stroke harmonic frequency;

[0089] Specifically, if the theoretical coding signal frequency is smaller than the pump stroke harmonic frequency at the main control harmonic order closest to the theoretical coding signal frequency, then the minimum value in the target pressure wave signal frequency range should be slightly smaller than the theoretical coding signal frequency, and the maximum value should be slightly larger than the pump stroke harmonic frequency at the main control harmonic order closest to the theoretical coding signal frequency; if the theoretical coding signal frequency is larger than the pump stroke harmonic frequency at the main control harmonic order closest to the theoretical coding signal frequency, then the maximum value in the target pressure wave signal frequency range should be slightly larger than the theoretical coding signal frequency, and the minimum value should be slightly smaller than the pump stroke harmonic frequency at the main control harmonic order closest to the theoretical coding signal frequency.

[0090] Step S204, performing a denoising process on the original pressure wave signal based on the target pressure wave signal frequency range to obtain a denoised pressure wave signal;

[0091] See also Figure 4 to Figure 7 ,in, Figure 4 is the time domain waveform of the original pressure wave signal, Figure 5 is the spectrum of the original pressure wave signal, Figure 6 is the time domain waveform of the pressure wave signal after denoising. Figure 7 The amplitude spectrum of the pressure wave signal after one denoising process is shown in Figure 2. It can be seen that one denoising process on the original pressure wave signal can remove the interference of low-frequency baseline noise and some random noise. The passband of the bandpass filter is 23-30 Hz.

[0092] Step S205, performing spectrum correction processing on the pressure wave signal after the primary denoising to obtain a target pump stroke harmonic amplitude, a target pump stroke harmonic frequency and a target pump stroke harmonic phase;

[0093] It should be noted that the pressure wave signal after primary denoising mainly contains the target pump harmonic noise, the coding signal and some random noise. Since the non-integer period truncation of the signal in the time domain will lead to spectrum leakage effect, and the discretization of the signal spectrum will lead to the fence effect, although the pressure wave signal spectrum after primary denoising can be obtained by directly performing fast Fourier transform on the pressure wave signal after primary denoising, its frequency resolution is usually poor. Although the fence effect can be reduced to a certain extent by padding zeros after the effective signal, the amount of data increases after zero padding, resulting in long processing time and poor real-time performance.

[0094] In the embodiment of the present invention, the spectrum of the pressure wave signal after primary denoising is corrected by using the interpolation spectrum correction technology. The basic principle of the interpolation spectrum correction technology is to use the ratio of the largest two or more spectral lines in the discrete spectrum to establish a function relationship with the frequency correction amount as a variable, and solve the correction frequency through the ratio to obtain a more accurate signal amplitude, frequency and phase. This method can effectively reduce the fence effect and spectrum leakage effect under the premise of increasing a small amount of calculation.

[0095] See also Figure 6 and Figure 7 , the frequency of the theoretical 6th target pump harmonic noise should be 28.8Hz, but its spectrum peak is 29.2969Hz, which has a certain error, and the amplitude corresponding to this frequency point is 2.5605 and the phase is -0.9458, which is very different from the true amplitude (3.5228) and phase (-1.5708). This will have a great impact on the reconstruction of the subsequent pump harmonic signal. Therefore, the pressure wave signal after the first denoising must be spectrally corrected. The specific process is as follows:

[0096] (1) Construct a Hanning window signal with the same number of time points as the pressure wave signal after the first denoising;

[0097] (2) multiplying the pressure wave signal after primary denoising by the Hanning window signal to obtain a windowed pressure wave signal;

[0098] (3) Calculate the frequency spectrum of the windowed pressure wave signal and find the two largest spectral lines in the frequency spectrum;

[0099] (4) Calculate the normalized frequency correction according to the following formula:

[0100]

[0101] in, is the normalized frequency correction amount, l is the maximum spectral line number, and X is the frequency of the windowed pressure wave signal.

[0102] (5) Correct the amplitude, frequency and phase of the pump harmonic signal according to the following formula:

[0103]

[0104]

[0105]

[0106] Where Δf is the frequency interval, a n is the amplitude of the pump harmonic signal, f n is the frequency, For phase.

[0107] See also Figure 8 , Figure 8 It is the amplitude spectrum of the pressure wave signal after spectrum correction. It can be seen that the frequency of the 6th target pump stroke harmonic noise after correction is 28.7942 Hz. The amplitude corresponding to this frequency point is 3.5383 and the phase is -1.5741, and the error with the true value is greatly reduced.

[0108] Step S206, reconstructing a target pump stroke harmonic noise based on the target pump stroke harmonic amplitude, the target pump stroke harmonic frequency and the target pump stroke harmonic phase;

[0109] Step S207, subtracting the target pump stroke harmonic noise from the primary denoised pressure wave signal to obtain a secondary denoised pressure wave signal;

[0110] Step S208, combining the secondary denoised pressure wave signal with the previously processed historical secondary denoised pressure wave signal to obtain a pressure wave signal to be decoded;

[0111] In the embodiment of the present invention, the pressure wave signal after secondary denoising obtained in this process is combined with the pressure wave signal after secondary denoising obtained in the previous process to obtain the pressure wave signal to be decoded. Fig. 9 The time domain waveform of the pressure wave signal after secondary denoising and Fig.10 The schematic diagram of the amplitude spectrum of the pressure wave signal after secondary denoising is shown in FIG.

[0112] Step S209: decoding the pressure wave signal to be decoded to obtain the downhole measurement data.

[0113] A method for suppressing pump impulse noise provided in an embodiment of the present invention includes: obtaining an estimated pump impulse harmonic frequency, a theoretical coding signal frequency and an original pressure wave signal, and performing a denoising process on the original pressure wave signal based on the estimated pump impulse harmonic frequency and the theoretical coding signal frequency to obtain a pressure wave signal after the denoising process; performing spectrum correction process on the pressure wave signal after the denoising process to obtain a target pump impulse harmonic amplitude, a target pump impulse harmonic frequency and a target pump impulse harmonic phase; reconstructing a target pump impulse harmonic noise based on the target pump impulse harmonic amplitude, the target pump impulse harmonic frequency and the target pump impulse harmonic phase; subtracting the target pump impulse harmonic noise from the pressure wave signal after the denoising process to obtain a pressure wave signal after the denoising process; and determining downhole measurement data based on the pressure wave signal after the denoising process. By obtaining relevant information of the pump impulse harmonic signal from the riser pressure wave signal and reconstructing the relevant information, effective extraction of the coded pulse can be achieved to meet the on-site needs of complex current conditions.

[0114] For example 3, please refer to Fig.11 , Fig.11 The present invention is a structural block diagram of a pump noise suppression device embodiment, comprising:

[0115] The acquisition module 301 is used to acquire the estimated pump stroke harmonic frequency, the theoretical coding signal frequency and the original pressure wave signal, and perform a denoising process on the original pressure wave signal based on the estimated pump stroke harmonic frequency and the theoretical coding signal frequency to obtain a denoised pressure wave signal;

[0116] A correction module 302 is used to perform spectrum correction processing on the pressure wave signal after the primary denoising to obtain a target pump stroke harmonic amplitude, a target pump stroke harmonic frequency and a target pump stroke harmonic phase;

[0117] A reconstruction module 303, configured to reconstruct a target pump stroke harmonic noise based on the target pump stroke harmonic amplitude, the target pump stroke harmonic frequency and the target pump stroke harmonic phase;

[0118] A secondary denoising module 304 is used to subtract the target pump impulse harmonic noise from the pressure wave signal after the primary denoising to obtain a pressure wave signal after the secondary denoising;

[0119] The downhole measurement data determination module 305 is used to determine the downhole measurement data according to the pressure wave signal after the secondary denoising.

[0120] In an optional embodiment, the downhole measurement data determination module 305 includes:

[0121] A pressure wave signal to be decoded determination submodule, used for combining the secondary denoised pressure wave signal with the previously processed historical secondary denoised pressure wave signal to obtain a pressure wave signal to be decoded;

[0122] The decoding submodule is used to decode the pressure wave signal to be decoded to obtain the downhole measurement data.

[0123] In an optional embodiment, the acquisition module includes:

[0124] An estimated pump stroke harmonic frequency determination submodule, used to determine the estimated pump stroke harmonic frequency based on the acquired pump stroke rate, the number of pump cylinders and the pump action mode;

[0125] A target pressure wave signal frequency range determination submodule, used to obtain a target pressure wave signal frequency range based on the acquired theoretical coded signal frequency and the estimated pump stroke harmonic frequency;

[0126] The primary denoising submodule is used to perform a primary denoising process on the original pressure wave signal based on the target pressure wave signal frequency range to obtain a primary denoised pressure wave signal.

[0127] In an optional embodiment, the estimated pump stroke harmonic frequency determination submodule includes:

[0128] A main control harmonic order determination unit, used to determine the order of the main control harmonic based on the number of cylinders of the pump and the action mode of the pump in combination with a preset main control harmonic order calculation expression;

[0129] The pump stroke harmonic frequency determination unit is used to determine the pump stroke harmonic frequency at the main control harmonic order based on the order of the main control harmonic and the pump stroke rate in combination with a preset pump stroke harmonic frequency calculation expression.

[0130] In an optional embodiment, the master control harmonic order calculation expression is:

[0131] n=m×N c ×a;

[0132] The pump stroke harmonic frequency calculation expression is:

[0133]

[0134] Among them, n is the number of main control harmonics; m is a positive integer; N c is the number of cylinders of the pump; a is the working mode, single-acting a is 1, double-acting a is 2, f n is the frequency of the nth harmonic; S is the pump stroke rate, that is, the number of pump strokes per minute.

[0135] An embodiment of the present invention further provides an electronic device, including a memory and a processor, wherein the memory stores a computer program, and when the computer program is executed by the processor, the processor executes the steps of a pump impulse noise suppression method as described in any of the above embodiments.

[0136] An embodiment of the present invention further provides a computer storage medium on which a computer program is stored. When the computer program is executed by the processor, the steps of a method for suppressing pump impulse noise as described in any of the above embodiments are implemented.

[0137] Those skilled in the art can clearly understand that, for the convenience and brevity of description, the specific working processes of the systems, devices and units described above can refer to the corresponding processes in the aforementioned method embodiments and will not be repeated here.

[0138] In the several embodiments provided in the present application, it should be understood that the methods, devices, electronic devices and storage media disclosed in the present invention can be implemented in other ways. For example, the device embodiments described above are only schematic. For example, the division of the units is only a logical function division. There may be other division methods in actual implementation, such as multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the mutual coupling or direct coupling or communication connection shown or discussed can be through some interfaces, indirect coupling or communication connection of devices or units, which can be electrical, mechanical or other forms.

[0139] The units described as separate components may or may not be physically separated, and the components shown as units may or may not be physical units, that is, they may be located in one place or distributed on multiple network units. Some or all of the units may be selected according to actual needs to achieve the purpose of the solution of this embodiment.

[0140] In addition, each functional unit in each embodiment of the present invention may be integrated into one processing unit, or each unit may exist physically separately, or two or more units may be integrated into one unit. The above-mentioned integrated unit may be implemented in the form of hardware or in the form of software functional units.

[0141] If the integrated unit is implemented in the form of a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the present invention is essentially or the part that contributes to the prior art or all or part of the technical solution can be embodied in the form of a software product. The computer software product is stored in a readable storage medium, including several instructions for a computer device (which can be a personal computer, a server, or a network device, etc.) to perform all or part of the steps of the method described in each embodiment of the present invention. The aforementioned readable storage medium includes: U disk, mobile hard disk, read-only memory (ROM, Read-Only Memory), random access memory (RAM, Random Access Memory), disk or optical disk and other media that can store program codes.

[0142] As described above, the above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit the same. Although the present invention has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that the technical solutions described in the aforementioned embodiments may still be modified, or some of the technical features thereof may be replaced by equivalents. However, these modifications or replacements do not deviate the essence of the corresponding technical solutions from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A method for suppressing pump noise, characterized in that: include: Acquire an estimated pump stroke harmonic frequency, a theoretical coding signal frequency, and an original pressure wave signal, and perform a denoising process on the original pressure wave signal based on the estimated pump stroke harmonic frequency and the theoretical coding signal frequency to obtain a denoised pressure wave signal; Performing spectrum correction processing on the pressure wave signal after the primary denoising to obtain a target pump stroke harmonic amplitude, a target pump stroke harmonic frequency and a target pump stroke harmonic phase; reconstructing a target pump stroke harmonic noise based on the target pump stroke harmonic amplitude, the target pump stroke harmonic frequency, and the target pump stroke harmonic phase; Subtracting the target pump stroke harmonic noise from the primary denoised pressure wave signal to obtain a secondary denoised pressure wave signal; The downhole measurement data is determined according to the secondary denoised pressure wave signal.

2. The method for suppressing pump noise according to claim 1, characterized in that: According to the secondary denoised pressure wave signal, downhole measurement data is obtained, including: Combining the secondary denoised pressure wave signal with the previously processed historical secondary denoised pressure wave signal to obtain a pressure wave signal to be decoded; The pressure wave signal to be decoded is decoded to obtain the downhole measurement data.

3. The method for suppressing pump noise according to claim 1, characterized in that: Acquiring an estimated pump stroke harmonic frequency, a theoretical coding signal frequency, and an original pressure wave signal, and performing a denoising process on the original pressure wave signal based on the estimated pump stroke harmonic frequency and the theoretical coding signal frequency to obtain a denoised pressure wave signal, including: Determine the estimated pump stroke harmonic frequency based on the obtained pump stroke rate, the number of pump cylinders and the pump action mode; Based on the acquired theoretical coded signal frequency and the estimated pump stroke harmonic frequency, acquiring a target pressure wave signal frequency range; Based on the target pressure wave signal frequency range, the original pressure wave signal is subjected to a denoising process to obtain a denoised pressure wave signal.

4. The method for suppressing pump noise according to claim 3, characterized in that: Based on the obtained pump stroke rate, number of pump cylinders and pump action mode, the estimated pump stroke harmonic frequency is determined, including: Based on the number of cylinders of the pump and the action mode of the pump, combined with a preset main control harmonic order calculation expression, the order of the main control harmonic is determined; Based on the order of the main control harmonic and the pump stroke rate, in combination with a preset pump stroke harmonic frequency calculation expression, the pump stroke harmonic frequency at the main control harmonic order is determined.

5. The method for suppressing pump noise according to claim 4, characterized in that: The calculation expression of the master control harmonic order is: n=m×N c ×a; The pump stroke harmonic frequency calculation expression is: Among them, n is the number of main control harmonics; m is a positive integer; N c is the number of cylinders of the pump; a is the working mode, single-acting a is 1, double-acting a is 2, f n is the frequency of the nth harmonic; S is the pump stroke rate, that is, the number of pump strokes per minute.

6. A drilling pump noise suppression device, characterized in that: include: An acquisition module, used to acquire an estimated pump stroke harmonic frequency, a theoretical coding signal frequency and an original pressure wave signal, and perform a denoising process on the original pressure wave signal based on the estimated pump stroke harmonic frequency and the theoretical coding signal frequency to obtain a denoised pressure wave signal; A correction module, used for performing spectrum correction processing on the pressure wave signal after the primary denoising to obtain a target pump stroke harmonic amplitude, a target pump stroke harmonic frequency and a target pump stroke harmonic phase; A reconstruction module, configured to reconstruct a target pump stroke harmonic noise based on the target pump stroke harmonic amplitude, the target pump stroke harmonic frequency and the target pump stroke harmonic phase; A secondary denoising module, used for subtracting the target pump impulse harmonic noise from the pressure wave signal after the primary denoising to obtain the pressure wave signal after the secondary denoising; The downhole measurement data determination module is used to determine the downhole measurement data according to the pressure wave signal after the secondary denoising.

7. The pump noise suppression device according to claim 6, characterized in that: The downhole measurement data determination module comprises: A pressure wave signal to be decoded determination submodule, used for combining the secondary denoised pressure wave signal with the previously processed historical secondary denoised pressure wave signal to obtain a pressure wave signal to be decoded; The decoding submodule is used to decode the pressure wave signal to be decoded to obtain the downhole measurement data.

8. The pump noise suppression device according to claim 6, characterized in that: The acquisition module comprises: An estimated pump stroke harmonic frequency determination submodule, used to determine the estimated pump stroke harmonic frequency based on the acquired pump stroke rate, the number of pump cylinders and the pump action mode; A target pressure wave signal frequency range determination submodule, used to obtain a target pressure wave signal frequency range based on the obtained theoretical coding signal frequency and the estimated pump stroke harmonic frequency; The primary denoising submodule is used to perform a primary denoising process on the original pressure wave signal based on the target pressure wave signal frequency range to obtain a primary denoised pressure wave signal.

9. An electronic device, characterized in that: The method comprises a processor and a memory, wherein the memory stores computer-readable instructions, and when the computer-readable instructions are executed by the processor, the method according to any one of claims 1 to 5 is executed.

10. A storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the method according to any one of claims 1 to 5 is performed.

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