Oil and gas well water production position positioning method, device and equipment based on distributed optical fiber sound waves and medium

Abstract

The invention relates to the technical field of oil and gas exploitation, and discloses an oil and gas well water production position positioning method, device and equipment based on distributed optical fiber sound waves and a medium, and acoustic signals corresponding to a plurality of production profiles can be collected through a distributed acoustic sensor arranged in an oil and gas shaft. And performing preprocessing, time-frequency conversion and normalization on the acoustic signal corresponding to each production profile to obtain a normalized acoustic spectrum corresponding to each production profile. And extracting a characteristic wave crest section from the normalized acoustic spectrum corresponding to each production profile. And carrying out reverse normalization on the characteristic wave crest segment corresponding to each production profile to obtain a reverse normalization wave crest segment. And based on the water phase response frequency band, determining a matched first wave crest section in the anti-normalized wave crest section corresponding to each production profile, and determining the production profile corresponding to each first wave crest section as a water production position. According to the invention, intelligent detection of the water production position of the oil and gas well can be realized, and the detection precision of the water production position is effectively improved.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas exploitation, and in particular to a method, device, equipment and medium for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves. Background Art

[0002] With the continuous growth of energy demand, the development of oil and gas resources has received extensive attention. Among them, natural gas has become an important research direction in oil and gas development due to its abundant reserves and huge potential.

[0003] During the natural gas development process, gas wells are often in a complex production state of simultaneous production of gas and water, and the precise positioning of the water production position is an important basis for optimizing gas well development plans and formulating production increase measures.

[0004] However, the related technology relies on technical personnel to rely on empirical analysis to determine the water production location, which has low accuracy. Summary of the invention

[0005] The present invention provides a method, device, equipment and medium for locating the water production position of oil and gas wells based on distributed optical fiber acoustic waves, which is used to solve the defect of low accuracy in related technologies that technicians rely on empirical analysis to determine the water production position, realize intelligent detection of the water production position of oil and gas wells, and effectively improve the detection accuracy of the water production position.

[0006] In a first aspect, the present invention provides a method for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves, comprising: Acoustic signals corresponding to multiple production profiles in the oil and gas wellbore are collected by using distributed acoustic sensors arranged in the oil and gas wellbore; Preprocessing, time-frequency conversion and normalization are performed on the acoustic signals corresponding to each of the production sections respectively to obtain a normalized acoustic spectrum corresponding to each of the production sections; Performing key characteristic peak detection in the normalized acoustic spectrum corresponding to each of the production profiles to extract the characteristic peak segment corresponding to each of the production profiles; Respectively denormalizing the characteristic peak segments corresponding to each of the production profiles to obtain denormalized peak segments corresponding to each of the production profiles; Based on the set water phase response frequency band, a matching first peak segment is determined in the inverse normalized peak segment corresponding to each production profile, and the production profile corresponding to each first peak segment is determined as the water production position.

[0007] Optionally, the preprocessing includes depth calibration and filtering; The preprocessing, time-frequency conversion and normalization of the acoustic signals corresponding to each of the production profiles are performed to obtain a normalized acoustic spectrum corresponding to each of the production profiles, including: respectively calibrating and filtering the acoustic signal corresponding to each of the production sections to obtain a filtered acoustic signal corresponding to each of the production sections; Performing time-frequency conversion on the filtered acoustic signal corresponding to each of the production sections respectively to obtain an acoustic spectrum corresponding to each of the production sections; The acoustic spectrum corresponding to each of the production sections is normalized respectively to obtain a normalized acoustic spectrum corresponding to each of the production sections.

[0008] Optionally, performing key characteristic peak detection in the normalized acoustic spectrum corresponding to each of the production profiles to extract characteristic peak segments corresponding to each of the production profiles includes: For the normalized acoustic spectrum corresponding to any of the production profiles, determine the data length and frequency range in the normalized acoustic spectrum, divide the data length by the frequency range to obtain the unit data density, determine the peak spacing constraint, peak width constraint and sensitivity window based on the unit data density, perform key feature peak detection in the normalized acoustic spectrum according to the set significance constraint, the peak spacing constraint, the peak width constraint and the sensitivity window, and extract the feature peak segment corresponding to the production profile.

[0009] Optionally, the denormalized peak segment corresponding to each of the production profiles includes a starting frequency and an ending frequency; The step of determining a matching first peak segment in the anti-normalized peak segment corresponding to each production profile based on the set water phase response frequency band includes: For the anti-normalized peak segment corresponding to any of the production profiles, if the starting frequency and the ending frequency in the anti-normalized peak segment are determined to be within the water phase response frequency band, then the anti-normalized peak segment is determined to be the first peak segment.

[0010] Optionally, after respectively performing denormalization on the characteristic peak segments corresponding to each of the production profiles to obtain the denormalized peak segments corresponding to each of the production profiles, the method further includes: Based on the set gas phase response frequency band, a matching second peak segment is determined in the inverse normalized peak segment corresponding to each of the production profiles, and the production profile corresponding to each of the second peak segments is determined as the gas production position.

[0011] Optionally, before determining the matching first peak segment in the denormalized peak segment corresponding to each production profile based on the set water phase response frequency band, the method includes: Based on the established fluid dynamics and acoustic coupling simulation model, the gas-water two-phase flow response characteristics are analyzed to determine the water phase response frequency band and the gas phase response frequency band.

[0012] Optionally, the gas-water two-phase flow response characteristic analysis based on the established fluid dynamics and acoustic coupling simulation model to determine the water phase response frequency band and the gas phase response frequency band includes: Establishing a dynamic flow field model of gas-water two-phase flow in a gas well horizontal well, coupling the dynamic flow field model of gas-water two-phase flow in the gas well horizontal well with acoustic simulation software to construct a fluid dynamics and acoustic coupling simulation model; In the wellbore acoustic field area of ​​the fluid dynamics and acoustic coupling simulation model, four field points are arranged in sequence from the inlet to the outlet, and four different gas-water ratios are used as typical working conditions to perform flow field and acoustic field joint transient simulation, and the sound pressure level frequency domain data of each field point is extracted; The amplitude distribution and the spectrum response law are determined by comparing the frequency domain data of the sound pressure level of each field point, and the gas phase response frequency band and the water phase response frequency band are determined based on the spectrum response law.

[0013] In a second aspect, the present invention provides a device for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves, comprising: A signal acquisition unit, used to acquire acoustic signals corresponding to a plurality of production profiles in the oil and gas wellbore through a distributed acoustic sensor arranged in the oil and gas wellbore; A signal processing unit, used to preprocess, time-frequency convert and normalize the acoustic signal corresponding to each of the production sections, to obtain a normalized acoustic spectrum corresponding to each of the production sections; A peak detection unit, used to perform key characteristic peak detection in the normalized acoustic spectrum corresponding to each of the production profiles, so as to extract a characteristic peak segment corresponding to each of the production profiles; A denormalization unit, used for respectively denormalizing the characteristic peak segment corresponding to each of the production profiles to obtain a denormalized peak segment corresponding to each of the production profiles; A peak matching unit, for determining a matching first peak segment in the denormalized peak segment corresponding to each of the production profiles based on a set water phase response frequency band; A water production positioning unit is used to determine the production profile corresponding to each of the first wave peak segments as a water production position.

[0014] In a third aspect, the present invention provides a computer device, comprising: a memory and a processor, the memory and the processor are communicatively connected to each other, the memory stores computer instructions, and the processor executes the method for locating water production positions in oil and gas wells based on distributed fiber optic acoustic waves according to the first aspect or any corresponding embodiment thereof by executing the computer instructions.

[0015] In a fourth aspect, the present invention provides a computer-readable storage medium having computer instructions stored thereon, the computer instructions being used to enable a computer to execute the method for locating water production positions in oil and gas wells based on distributed fiber optic acoustic waves according to the first aspect or any corresponding embodiment thereof.

[0016] The method, device, equipment and medium for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves provided by the present invention can collect acoustic signals corresponding to multiple production profiles in the oil and gas wellbore through a distributed acoustic sensor arranged in the oil and gas wellbore. The acoustic signals corresponding to each production profile are preprocessed, time-frequency converted and normalized respectively to obtain a normalized acoustic spectrum corresponding to each production profile. Key characteristic peak detection is performed in the normalized acoustic spectrum corresponding to each production profile respectively to extract the characteristic peak segment corresponding to each production profile. The characteristic peak segment corresponding to each production profile is reversed and normalized respectively to obtain the reversed normalized peak segment corresponding to each production profile. Based on the set water phase response frequency band, the first matching peak segment is determined in the reversed normalized peak segment corresponding to each production profile respectively, and the production profile corresponding to each first peak segment is determined as the water production position. The present invention can perform acoustic spectrum processing based on the acoustic signal corresponding to the production profile to realize intelligent detection of the water production position of the oil and gas well, and effectively improve the detection accuracy of the water production position. BRIEF DESCRIPTION OF THE DRAWINGS

[0017] In order to more clearly illustrate the technical solutions in the present invention or related technologies, the following briefly introduces the drawings required for use in the embodiments or related technical descriptions. Obviously, the drawings described below are some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative work.

[0018] Figure 1 A flow chart of a method for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves provided in an embodiment of the present invention; Figure 2 A geometric diagram of a peak detection-related constraint provided by an embodiment of the present invention; Figure 3 A schematic diagram of simulation results and acquisition point locations of a joint simulation model provided by an embodiment of the present invention; Figure 4 A flow chart of another method for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves provided by an embodiment of the present invention; Figure 5 An acoustic spectrum diagram provided by an embodiment of the present invention; Figure 6 A normalized acoustic spectrum diagram provided by an embodiment of the present invention; Figure 7 A schematic diagram of a characteristic peak segment in a normalized acoustic spectrum diagram provided by an embodiment of the present invention; Figure 8 A schematic diagram of a denormalized characteristic peak segment provided by an embodiment of the present invention; Fig. 9 A relevant acoustic data diagram corresponding to a production profile provided in an embodiment of the present invention; Fig.10 Another acoustic spectrum diagram provided by an embodiment of the present invention; Fig.11 Another normalized acoustic spectrum diagram provided by an embodiment of the present invention; Fig.12 A schematic diagram of another characteristic peak segment in a normalized acoustic spectrum provided by an embodiment of the present invention; Fig.13 A schematic diagram of another denormalized characteristic peak segment provided by an embodiment of the present invention; Fig.14 A graph of related acoustic data corresponding to another production profile provided in an embodiment of the present invention; Fig.15 A schematic diagram of the structure of a device for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves provided in an embodiment of the present invention; Fig.16 A schematic diagram of the structure of a computer device provided in an embodiment of the present invention. DETAILED DESCRIPTION

[0019] In order to make the purpose, technical solution and advantages of the present invention clearer, the technical solution of the present invention will be clearly and completely described below in conjunction with the drawings of the present invention. Obviously, the described embodiments are 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.

[0020] Combine the following Figure 1-Figure 14 The invention describes a method for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves.

[0021] like Figure 1 As shown, this embodiment proposes a first method for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves. The method may include the following steps: S101. Acoustic signals corresponding to multiple production profiles in the oil and gas wellbore are collected by using distributed acoustic sensors arranged in the oil and gas wellbore.

[0022] Among them, the multiple production profiles in the oil and gas wellbore may be production profiles at different wellbore depths.

[0023] Specifically, in this embodiment, a distributed acoustic sensor may be arranged in the oil and gas wellbore, and acoustic signals may be collected at multiple production sections of the oil and gas wellbore through the distributed acoustic sensor to obtain an acoustic signal corresponding to each production section.

[0024] It should be noted that distributed acoustic sensing (DAS) technology has shown great application potential in the field of gas well production monitoring due to its real-time performance, stability and full well coverage. This embodiment can collect acoustic signals in the wellbore in real time through distributed acoustic sensors, namely optical fiber sensors, and can capture the acoustic characteristics generated by gas-water two-phase flow.

[0025] S102, preprocessing, time-frequency conversion and normalization are performed on the acoustic signal corresponding to each production profile to obtain a normalized acoustic spectrum corresponding to each production profile.

[0026] Specifically, in this embodiment, for an acoustic signal corresponding to any production profile, the acoustic signal corresponding to the production profile can be preprocessed, video converted, and normalized in sequence to obtain a normalized acoustic spectrum corresponding to the production profile.

[0027] Optionally, the preprocessing includes depth calibration and filtering. Step S102 may include: The acoustic signal corresponding to each production section is calibrated and filtered respectively to obtain the filtered acoustic signal corresponding to each production section; Perform time-frequency conversion on the filtered acoustic signal corresponding to each production section to obtain the acoustic spectrum corresponding to each production section; The acoustic spectrum corresponding to each production profile is normalized respectively to obtain a normalized acoustic spectrum corresponding to each production profile.

[0028] It should be noted that during the construction process, the optical fiber usually has some redundancy on the ground, and its initial measurement position is not the actual wellhead position. In addition, the actual length of the optical fiber in the wellbore may not completely correspond to the actual sounding of the wellbore due to stretching or spiral distribution. Therefore, the position of the optical fiber measuring point needs to be recalculated to accurately match the actual sounding position and fracturing level position in the wellbore. Most of the DAS raw data contain calibration information, but the calibration information content in the data varies depending on the test supplier. Usually, only the calibration information of some measuring points is provided, and in a few cases, the calibration information of the measuring points of the entire wellbore is included. The calibration of DAS data in subsequent example applications of the present invention is based on the calibration information contained in the raw data. Filtering refers to one of the methods for removing unnecessary components in the signal. In order to extract data in the required frequency band, it is usually necessary to build a digital filter to filter the optical fiber signal after depth calibration. First, a digital analog filter is established. The Butterworth low-pass filter established in this embodiment is:

[0029] in, is the filter order, Yes -3 dB The cut-off frequency, is the starting frequency, is a virtual function, The order of the Butterworth low-pass filter can be determined by the following formula:

[0030]

[0031]

[0032] in, S is the pole of the analog filter, The present embodiment may use a band-pass filter, and convert the frequency of the low-pass filter by the following method to obtain a band-pass filter.

[0033]

[0034]

[0035]

[0036] in, is the passband width, is the center frequency, is the initial frequency, In actual operation, it is only necessary to calculate the initial frequency parameter and the cutoff frequency parameter corresponding to the required frequency range.

[0037] It should be noted that the acoustic signal corresponding to the production profile and the acoustic signal after filtering are both time domain data. This embodiment can perform time-frequency conversion on the time domain data to facilitate subsequent energy bottle analysis and spectrum analysis.

[0038] Specifically, this embodiment can perform time-frequency conversion on the filtered acoustic signal corresponding to each production section based on Fourier transform to obtain the acoustic spectrum corresponding to each production section.

[0039] Specifically, this embodiment can normalize the acoustic spectrum corresponding to each production profile, eliminate the energy difference between signals, and adjust the value of the signal to a uniform range.

[0040] In this embodiment, the acoustic spectrum corresponding to each production profile can be normalized based on the minimum-maximum normalization method. Specifically, for the acoustic spectrum corresponding to any production profile, the embodiment can determine the maximum frequency and the minimum frequency in the acoustic spectrum, and then normalize each frequency in the acoustic spectrum based on the maximum frequency and the minimum frequency.

[0041] It should be noted that, in this embodiment, by normalizing the acoustic spectrum corresponding to each generated profile, data of different frequency bands can be compared and processed at a unified scale, thereby ensuring the consistency and accuracy of subsequent peak detection and analysis.

[0042] S103, performing key characteristic peak detection in the normalized acoustic spectrum corresponding to each production profile, so as to extract the characteristic peak segment corresponding to each production profile.

[0043] Specifically, this embodiment can perform peak searches in normalized acoustic spectra corresponding to different production profiles, so as to extract characteristic peak segments from the normalized acoustic spectra corresponding to different production profiles.

[0044] Optionally, step S103 may include: For the normalized acoustic spectrum corresponding to any production profile, determine the data length and frequency range in the normalized acoustic spectrum, divide the data length by the frequency range to obtain the unit data density, and determine the peak spacing constraint, peak width constraint and sensitivity window based on the unit data density. According to the set significance constraint, peak spacing constraint, peak width constraint and sensitivity window, perform key feature peak detection in the normalized acoustic spectrum to extract the characteristic peak segment corresponding to the production profile.

[0045] like Figure 2As shown, the present embodiment can define relevant constraints and geometric features. Through relevant constraints and geometric features, the present embodiment can effectively extract the characteristic peak segments in the normalized acoustic spectrum, i.e., the DAS spectrum, based on the gas well water production location positioning method based on the DAS acoustic spectrum analysis and the peak morphology constraint mechanism, enhance the accuracy and reliability of signal analysis, and provide a solid technical foundation for the positioning of gas and water production distribution in gas wells.

[0046] Specifically, this embodiment may first define a unit data density variable to unify the data processing dimension. In order to unify the data processing methods under different resolutions and time window scenarios, this embodiment may define a unit data density variable unit , which is expressed as follows:

[0047] in, is the data length in the normalized acoustic spectrum, is the maximum monitoring frequency. Assuming the data length is 300000 and the monitoring frequency is 0-200Hz, then 1500, which means that under the current monitoring conditions, 1500 data points are required to describe each 1Hz frequency band. By defining this unit data density variable, unified data description and analysis can be performed under different sampling resolutions and time windows, making the subsequent parameter adjustment and comparison more convenient, thereby simplifying the data processing process in different scenarios and improving the applicability of the method.

[0048] Specifically, this embodiment can define the peak search process and constraints of the normalized acoustic spectrum, that is, the DAS spectrum feature. For the search process, this embodiment can give a one-dimensional signal , first scan the signal and determine the local maximum. If for a certain point ,satisfy:

[0049] in, is the neighborhood size. Then we assume is a peak value.

[0050] Specifically, this embodiment can set a significance constraint. Significance measures the prominence of a peak. The calculation of significance is based on the left and right baselines of the peak. In the search range on the left and right sides of the peak, the minimum value of the signal value is found respectively, and these minimum values ​​(left and right) are defined as the left and right baselines of the current peak. The larger value of the left and right baselines is defined as the lowest contour line of the current peak. For each peak , defining significance for:

[0051] in, is the peak position, and Represent the baselines to the left and right of the peak, respectively.

[0052] Specifically, in this embodiment, a peak width constraint can be set. The peak width measures the width of the peak, and the width is defined as the distance between points where the peak significance reaches a certain ratio. Taking a 95% significance ratio as an example, assuming that the maximum height of the peak is , the calculation of its significance width is as follows:

[0053] in, and They are the positions of the points reaching a certain significance (95%) to the right and to the left from the peak, respectively. It is used to limit the detected peaks to have actual physical meaning and sufficient frequency coverage, so that when the significance is set to 1, it means calculating the width of the entire peak.

[0054] Specifically, the present embodiment may define a sensitivity window constraint. The sensitivity window determines the window range when calculating the peak significance, which directly affects the determination of the baseline height and the sensitivity of the peak detection. The shorter the window length, the more sensitive the detected peak is, but noise may be introduced. The longer the window length, the smoother the small fluctuations and the more significant characteristic peaks can be focused.

[0055] Specifically, this embodiment may define a peak spacing constraint. The peak spacing limits the minimum distance between two adjacent peaks, reducing the occurrence of overlapping peaks while ensuring that the identified frequency bands have a certain degree of separation. Suppose the minimum peak spacing is , for two adjacent peaks and , must meet the following requirements:

[0056] It should be noted that the peak spacing constraint can effectively reduce the interference of overlapping peaks and improve the accuracy and independence of frequency band feature extraction.

[0057] Specifically, this embodiment can detect in the normalized acoustic spectrum by the above constraints. unit The characteristic peak segments are extracted by adjusting the algorithm parameters to adapt to different well sections or complex signal conditions.

[0058] S104, respectively denormalize the characteristic peak segment corresponding to each production profile to obtain a denormalized peak segment corresponding to each production profile.

[0059] Specifically, this embodiment performs denormalization on characteristic peak segments corresponding to different generated profiles to obtain denormalized peak segments corresponding to different production profiles.

[0060] S105. Based on the set water phase response frequency band, determine the matching first peak segment in the denormalized peak segment corresponding to each production profile.

[0061] Among them, the first peak segment is the peak segment that matches the water phase response frequency band in the anti-normalized peak segment corresponding to the production profile.

[0062] It should be noted that the flow patterns (flow types) of gas-water two-phase flow in horizontal well sections are diverse, and the spectra and response bands corresponding to different flow patterns are significantly different. Based on this law, the corresponding acoustic characteristic frequency bands are accurately extracted by dynamically constraining the peak search of the DAS signal spectrum, and the corresponding water production position is determined by combining the spectrum characteristics of the gas-water flow pattern. This method can overcome the limitations of traditional methods that rely on empirical analysis and achieve real-time water production position positioning with higher accuracy and greater adaptability.

[0063] Specifically, in this embodiment, according to a preset water phase response frequency band, a matching first peak segment can be determined from the inverse normalized peak segments corresponding to different production profiles.

[0064] Optionally, the denormalized peak segment corresponding to each production profile includes a starting frequency and an ending frequency. In this case, step S105 may include: For the anti-normalized peak segment corresponding to any production profile, if the starting frequency and the ending frequency in the anti-normalized peak segment are determined to be within the water phase response frequency band, the anti-normalized peak segment is determined to be the first peak segment.

[0065] Specifically, in this embodiment, for a denormalized peak segment corresponding to any production profile, when it is determined that the starting frequency and the ending frequency in the denormalized peak segment are both within the water phase response frequency band, the denormalized peak segment can be determined to be the first peak segment.

[0066] S106. Determine the production profile corresponding to each first wave peak segment as the water production position.

[0067] Specifically, in this embodiment, the production profile corresponding to each determined first wave peak segment can be determined as the water production position.

[0068] Optionally, in other methods for locating water production positions in oil and gas wells based on distributed optical fiber acoustic waves proposed in this embodiment, the method may further include, after step S105: Based on the set gas phase response frequency band, a matching second peak segment is determined in the anti-normalized peak segment corresponding to each production profile, and the production profile corresponding to each second peak segment is determined as the gas production position.

[0069] Specifically, in this embodiment, for a denormalized peak segment corresponding to any production profile, when it is determined that the starting frequency and the ending frequency in the denormalized peak segment are both within the gas phase response frequency band, the denormalized peak segment can be determined to be a second peak segment. Afterwards, this embodiment can determine the production profile corresponding to each determined second peak segment as a gas production position.

[0070] It can be understood that this embodiment can accurately locate the water production position of the gas well, thereby achieving efficient monitoring and accurate evaluation of the production status of the gas well.

[0071] The method for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves proposed in this embodiment can collect acoustic signals corresponding to multiple production profiles in the oil and gas wellbore through a distributed acoustic sensor set in the oil and gas wellbore. The acoustic signals corresponding to each production profile are preprocessed, time-frequency converted and normalized respectively to obtain a normalized acoustic spectrum corresponding to each production profile. Key characteristic peak detection is performed in the normalized acoustic spectrum corresponding to each production profile to extract the characteristic peak segment corresponding to each production profile. The characteristic peak segment corresponding to each production profile is reversed and normalized to obtain the reversed normalized peak segment corresponding to each production profile. Based on the set water phase response frequency band, the matching first peak segment is determined in the reversed normalized peak segment corresponding to each production profile, and the production profile corresponding to each first peak segment is determined as the water production position. This embodiment can perform acoustic spectrum processing based on the acoustic signal corresponding to the production profile to realize intelligent detection of the water production position of the oil and gas well, and effectively improve the detection accuracy of the water production position.

[0072] based on Figure 1 This embodiment proposes a second method for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves. Before step S105, the method further includes: Based on the established fluid dynamics and acoustic coupling simulation model, the gas-water two-phase flow response characteristics are analyzed to determine the water phase response frequency band and the gas phase response frequency band.

[0073] Specifically, this embodiment can establish a fluid dynamics and acoustic coupling simulation model, and use the model to perform simulation experiments to determine the water phase response frequency band and the gas phase response frequency band.

[0074] Optionally, the gas-water two-phase flow response characteristic analysis based on the established fluid dynamics and acoustic coupling simulation model to determine the water phase response frequency band and the gas phase response frequency band includes: Establish a dynamic flow field model of gas-water two-phase flow in a gas well horizontal well, and couple the dynamic flow field model of gas-water two-phase flow in a gas well horizontal well with acoustic simulation software to construct a fluid dynamics and acoustic coupling simulation model; In the wellbore acoustic field area of ​​the fluid dynamics and acoustic coupling simulation model, four field points are arranged in sequence from the inlet to the outlet, and four different gas-water ratios are used as typical working conditions to perform flow field and acoustic field joint transient simulation, and the sound pressure level frequency domain data of each field point are extracted; The amplitude distribution and spectrum response law are determined by comparing the frequency domain data of the sound pressure level at each field point, and the gas phase response frequency band and the water phase response frequency band are determined based on the spectrum response law.

[0075] Specifically, this embodiment can be based on the analysis of the gas-water two-phase flow response characteristics of the fluid dynamics (CFD) and acoustic coupling simulation model. First, the CFD fluid simulation software is used to establish a dynamic flow field model of gas-water two-phase flow in a gas well horizontal well, and the acoustic simulation software is coupled to build a flow field-acoustic field bidirectional correlation calculation system, and four gas-water ratios of 0.1, 1, 5, and 10 are set as typical working conditions. Four field points (field point 1 to field point 4) are arranged in sequence from the inlet to the outlet in the wellbore acoustic field area, and a flow-acoustic field joint transient simulation is performed.

[0076] like Figure 3 As shown, this embodiment can extract the sound pressure level-frequency domain data of each field point and compare the amplitude distribution and spectrum response law. The simulation results show that as the gas-water ratio increases, the sound pressure level gain is significant, and the peak frequency band expands to high frequency, where the response frequency band of the gas phase is mainly 10-50Hz, and the response frequency band of the water phase is 5-10Hz. The two-phase difference response characteristics provide a quantitative basis for the frequency domain identification threshold parameters of the water production section, which is used to explore the response characteristics of the water-gas two-phase flow in the acoustic field under different gas-water ratios, so as to achieve accurate positioning of the water production position of the gas well.

[0077] like Figure 4 As shown, in other oil and gas well water production location positioning methods based on distributed optical fiber acoustic waves proposed in this embodiment, the method may include the following steps: Obtain the DAS monitoring data of a production profile at a certain depth in an oil and gas well, that is, the acoustic signal corresponding to the production profile. Preprocess the acoustic signal and convert it into time-frequency domain to obtain the acoustic spectrum. Then calculate the energy bottle and perform SG filtering to smooth the curve, and then normalize it to obtain the normalized acoustic spectrum.

[0078] Peak detection is performed based on the normalized acoustic spectrum. Specifically, this embodiment can find the peak point position, calculate the peak baseline, significance, peak width and adjacent peak distance, optimize the constraint parameters with a genetic algorithm, and determine whether it is the optimal solution. If so, it can return to the operation of finding the peak point position until the valid peak segment is determined. Output the characteristic frequency band.

[0079] In order to better introduce the positioning process of the water production position and the gas production position, this embodiment proposes Example 1 and Example 2 for illustration in combination with actual practice.

[0080] Wherein, Example 1 specifically comprises the following steps: (1) Take the acoustic signal corresponding to a production section of the well during production, and perform preprocessing and time-frequency conversion on it. The converted spectrum is shown in the figure below: Figure 5 shown.

[0081] (2) Normalize the spectrum graph by the minimum and maximum values ​​MinMax, and obtain Figure 6 Normalized acoustic spectrum shown.

[0082] (3) Check the data length of the current spectrum graph. In this embodiment, the data length is 6000 and the frequency range is 0-100 Hz. Define unit =60, which means that in the current example, there are 60 data points in each 1 Hz frequency band.

[0083] (4) According to the data situation, the significance constraint is set to 0.073, that is, in the normalized acoustic spectrum, data points with a peak-to-peak significance less than 0.073 are not considered valid peak points; the peak spacing constraint is one unit The length of the peak is , that is, the distance between two effective peaks should be at least 60 data points; the peak width constraint is unit , that is, the entire peak contains at least 60 data points; the sensitivity window is set to 5 unit , that is, the current algorithm calculation window is 5 unit length.

[0084] (5) Using the peak extraction algorithm proposed in this embodiment and the parameters set in step (4), the normalized acoustic spectrum is tested. The test results are as follows: Figure 7 shown.

[0085] (6) Denormalize the normalized acoustic spectrum and calculate the numerical results of the peak search algorithm, such as Figure 8 and Fig. 9 It can be seen from the table that the response frequency band of the production profile is mainly distributed in the water phase response frequency band range of 5-10Hz.

[0086] Example 2 specifically includes the following steps: (1) The acoustic wave signal corresponding to a section of the well different from that in Example 1 is obtained during production, and the acoustic wave signal is preprocessed and time-frequency converted to obtain a converted spectrum diagram as shown in FIG. Fig.10 shown.

[0087] (2) Normalize the spectrum graph by the minimum and maximum values ​​MinMax, and obtain Fig.11 Normalized acoustic spectrum shown.

[0088] (3) Check the data length of the current spectrum graph. In this embodiment, the data length is 6000 and the frequency range is 0-100 Hz. Define unit =60, which means that in the current example, there are 60 data points in each 1 Hz frequency band.

[0089] (4) According to the data situation, the significance constraint is set to 0.075, that is, in the normalized acoustic spectrum, data points with a peak-to-peak significance less than 0.075 are not considered valid peak points; the peak spacing constraint is one unit The length of the peak is , that is, the distance between two effective peaks should be at least 60 data points; the peak width constraint is unit , that is, the entire peak contains at least 60 data points; the sensitivity window is set to 5 unit , that is, the current algorithm calculation window is 5 unit length.

[0090] (5) Using the peak extraction algorithm proposed in this embodiment and the parameters set in step (4), the normalized acoustic spectrum is tested. The test results are as follows: Fig.12 shown.

[0091] (6) Denormalize the normalized acoustic spectrum and calculate the numerical results of the peak search algorithm, such as Fig.13 and Fig.14 From the table, it can be seen that the response frequency band corresponding to the production profile of Example 2 is mainly distributed in the gas phase response frequency band range of 10-15Hz.

[0092] It is understandable that Example 2 and Example 1 are based on the same set of parameter settings, which can better achieve the extraction of characteristic frequency bands of different production profiles of the well. This unified parameter setting not only improves the applicability of the method, but also significantly reduces the workload of parameter adjustment under complex working conditions. According to the extracted characteristic frequency bands, they are compared and analyzed with the spectral characteristics and response frequency bands corresponding to different manifolds, so as to quickly locate the water production position and generate the production profile distribution in the wellbore.

[0093] It should be noted that production profile monitoring technologies in related technologies, such as temperature logging, pressure logging and cable acoustic logging, can provide certain water production information, but their applicability, real-time and resolution are limited, especially in complex working conditions such as horizontal wells and branch wells, and it is difficult to meet actual needs. In addition, conventional methods require multiple downhole operations, which are costly, inefficient, and easily affected by the complex wellbore environment (such as multiphase flow, noise interference, etc.), resulting in greater uncertainty in the measurement results.

[0094] Specifically, this embodiment realizes the rapid determination of the water production position of the gas well by extracting the acoustic characteristic peaks of different frequency bands and combining the wellbore depth information. Compared with the empirical analysis based on the relevant technology, this embodiment has significant advantages in significance, real-time and applicability, and has important engineering practice significance and theoretical research value for gas well production monitoring and optimization management under complex working conditions.

[0095] The method for locating the water production position of oil and gas wells based on distributed fiber optic acoustic waves proposed in this embodiment can, to a certain extent, solve the problem of production profile analysis under complex gas-water two-phase flow conditions. It can quickly and accurately extract the characteristic frequency bands of the production profile, and combine the response distribution of gas and water in different frequency ranges. It effectively improves the real-time and reliability of gas well water production position determination, which is of great significance to the production optimization and management of oil fields.

[0096] like Fig.15 As shown, this embodiment proposes a device for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves, comprising: The signal acquisition unit 1501 is used to collect acoustic signals corresponding to multiple production profiles in the oil and gas wellbore through a distributed acoustic sensor arranged in the oil and gas wellbore; The signal processing unit 1502 is used to preprocess, time-frequency convert and normalize the acoustic signal corresponding to each production section to obtain a normalized acoustic spectrum corresponding to each production section; The peak detection unit 1503 is used to perform key characteristic peak detection in the normalized acoustic spectrum corresponding to each production profile, so as to extract the characteristic peak segment corresponding to each production profile; The anti-normalization unit 1504 is used to perform anti-normalization on the characteristic peak segment corresponding to each production profile to obtain the anti-normalized peak segment corresponding to each production profile; The peak matching unit 1505 is used to determine the first matching peak segment in the denormalized peak segment corresponding to each production profile based on the set water phase response frequency band; The water production positioning unit 1506 is used to determine the production profile corresponding to each first wave peak segment as the water production position.

[0097] It should be noted that the processing processes of the signal acquisition unit 1501, the signal processing unit 1502, the peak detection unit 1503, the denormalization unit 1504, the peak matching unit 1505 and the water production positioning unit 1506 and the beneficial effects thereof can be referred to respectively. Figure 1 Steps S101 to S105 in the above are not described in detail.

[0098] Optionally, the preprocessing includes depth calibration and filtering. The signal processing unit 1502 is also used for: The acoustic signal corresponding to each production section is calibrated and filtered respectively to obtain the filtered acoustic signal corresponding to each production section; Perform time-frequency conversion on the filtered acoustic signal corresponding to each production section to obtain the acoustic spectrum corresponding to each production section; The acoustic spectrum corresponding to each production profile is normalized respectively to obtain a normalized acoustic spectrum corresponding to each production profile.

[0099] Optionally, the peak detection unit 1503 is further configured to: For the normalized acoustic spectrum corresponding to any production profile, determine the data length and frequency range in the normalized acoustic spectrum, divide the data length by the frequency range to obtain the unit data density, and determine the peak spacing constraint, peak width constraint and sensitivity window based on the unit data density. According to the set significance constraint, peak spacing constraint, peak width constraint and sensitivity window, perform key feature peak detection in the normalized acoustic spectrum to extract the characteristic peak segment corresponding to the production profile.

[0100] Optionally, the denormalized peak segment corresponding to each production profile includes a start frequency and an end frequency; The peak matching unit 1505 is further used for: For the anti-normalized peak segment corresponding to any production profile, if the starting frequency and the ending frequency in the anti-normalized peak segment are determined to be within the water phase response frequency band, the anti-normalized peak segment is determined to be the first peak segment.

[0101] Optionally, the peak matching unit 1505 is further used for: After respectively denormalizing the characteristic peak segments corresponding to each production profile to obtain the denormalized peak segments corresponding to each production profile, based on the set gas phase response frequency band, a matching second peak segment is determined in the denormalized peak segment corresponding to each production profile, and the production profile corresponding to each second peak segment is determined as the gas production position.

[0102] Optionally, the above device further includes: The gas-water frequency band determination unit is used to perform gas-water two-phase flow response characteristic analysis based on the established fluid dynamics and acoustic coupling simulation model to determine the water phase response frequency band and the gas phase response frequency band before determining the matching first peak segment in the anti-normalized peak segment corresponding to each production profile based on the set water phase response frequency band.

[0103] The oil and gas well water production position positioning device based on distributed optical fiber acoustic waves proposed in this embodiment can collect acoustic signals corresponding to multiple production profiles in the oil and gas wellbore through a distributed acoustic sensor set in the oil and gas wellbore. The acoustic signals corresponding to each production profile are preprocessed, time-frequency converted and normalized respectively to obtain the normalized acoustic spectrum corresponding to each production profile. Key characteristic peak detection is performed in the normalized acoustic spectrum corresponding to each production profile to extract the characteristic peak segment corresponding to each production profile. The characteristic peak segment corresponding to each production profile is reversed and normalized to obtain the reversed normalized peak segment corresponding to each production profile. Based on the set water phase response frequency band, the matching first peak segment is determined in the reversed normalized peak segment corresponding to each production profile, and the production profile corresponding to each first peak segment is determined as the water production position. This embodiment can perform acoustic spectrum processing based on the acoustic signal corresponding to the production profile to realize intelligent detection of the water production position of the oil and gas well, and effectively improve the detection accuracy of the water production position.

[0104] The oil and gas well water production position positioning device based on distributed fiber optic acoustic waves in this embodiment is presented in the form of a functional unit, where the unit refers to an ASIC (Application Specific Integrated Circuit) circuit, a processor and memory that executes one or more software or fixed programs, and / or other devices that can provide the above functions.

[0105] The embodiment of the present invention also provides a computer device having the above Fig.15 The device shown is for locating the water production position of an oil and gas well based on distributed fiber optic acoustic waves.

[0106] See also Fig.16 , a schematic diagram of the structure of a computer device provided by an optional embodiment of the present invention, the computer device includes: one or more processors 10, a memory 20, and interfaces for connecting various components, including high-speed interfaces and low-speed interfaces. The various components are connected to each other using different buses for communication, and can be installed on a common mainboard or installed in other ways as needed. The processor can process instructions executed in the computer device, including instructions stored in or on the memory to display graphical information of the GUI on an external input / output device (such as a display device coupled to the interface). In some optional embodiments, if necessary, multiple processors and / or multiple buses can be used together with multiple memories. Similarly, multiple computer devices can be connected, and each device provides part of the necessary operations (for example, as a server array, a group of blade servers, or a multi-processor system). Fig.16 A processor 10 is taken as an example.

[0107] The processor 10 may be a central processing unit, a network processor or a combination thereof. The processor 10 may further include a hardware chip. The hardware chip may be a dedicated integrated circuit, a programmable logic device or a combination thereof. The programmable logic device may be a complex programmable logic device, a field programmable gate array, a general purpose array logic or any combination thereof.

[0108] The memory 20 stores instructions executable by at least one processor 10, so that at least one processor 10 executes the method shown in the above embodiment.

[0109] The memory 20 may include a program storage area and a data storage area, wherein the program storage area may store an operating system, an application required for at least one function. The data storage area may store data created according to the use of the computer device, etc. In addition, the memory 20 may include a high-speed random access memory, and may also include a non-transient memory, such as at least one disk storage device, a flash memory device, or other non-transient solid-state storage devices. In some optional embodiments, the memory 20 may optionally include a memory remotely arranged relative to the processor 10, and these remote memories may be connected to the computer device via a network. Examples of the above-mentioned network include, but are not limited to, the Internet, an intranet, a local area network, a mobile communication network, and combinations thereof.

[0110] The memory 20 may include a volatile memory, such as a random access memory. The memory may also include a non-volatile memory, such as a flash memory, a hard disk or a solid state drive. The memory 20 may also include a combination of the above-mentioned types of memory.

[0111] The computer device further comprises a communication interface 30 for the computer device to communicate with other devices or a communication network.

[0112] The embodiment of the present invention also provides a computer-readable storage medium. The method according to the embodiment of the present invention can be implemented in hardware, firmware, or can be implemented as a computer code that can be recorded in a storage medium, or can be implemented as a computer code that is originally stored in a remote storage medium or a non-temporary machine-readable storage medium and will be stored in a local storage medium through a network download, so that the method described herein can be stored in such software processing on a storage medium using a general-purpose computer, a dedicated processor, or programmable or dedicated hardware. Among them, the storage medium can be a magnetic disk, an optical disk, a read-only storage memory, a random access memory, a flash memory, a hard disk or a solid-state hard disk, etc.; further, the storage medium can also include a combination of the above types of memories. It can be understood that a computer, a processor, a microprocessor controller, or programmable hardware includes a storage component that can store or receive software or computer code. When the software or computer code is accessed and executed by a computer, a processor, or hardware, the method shown in the above embodiment is implemented.

[0113] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit it. Although the present invention has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or make equivalent replacements for some of the technical features therein. 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 locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves, characterized in that: include: Acoustic signals corresponding to multiple production profiles in the oil and gas wellbore are collected by using distributed acoustic sensors arranged in the oil and gas wellbore; Preprocessing, time-frequency conversion and normalization are performed on the acoustic signals corresponding to each of the production sections respectively to obtain a normalized acoustic spectrum corresponding to each of the production sections; Performing key characteristic peak detection in the normalized acoustic spectrum corresponding to each of the production profiles to extract the characteristic peak segment corresponding to each of the production profiles; Respectively denormalizing the characteristic peak segments corresponding to each of the production profiles to obtain denormalized peak segments corresponding to each of the production profiles; Based on the set water phase response frequency band, a matching first peak segment is determined in the inverse normalized peak segment corresponding to each of the production profiles, and the production profile corresponding to each of the first peak segments is determined as the water production position.

2. The method according to claim 1, characterized in that The preprocessing includes depth calibration and filtering; The preprocessing, time-frequency conversion and normalization of the acoustic signals corresponding to each of the production profiles are performed to obtain a normalized acoustic spectrum corresponding to each of the production profiles, including: respectively calibrating and filtering the acoustic signal corresponding to each of the production sections to obtain a filtered acoustic signal corresponding to each of the production sections; Performing time-frequency conversion on the filtered acoustic signal corresponding to each of the production sections respectively to obtain an acoustic spectrum corresponding to each of the production sections; The acoustic spectrum corresponding to each of the production sections is normalized respectively to obtain a normalized acoustic spectrum corresponding to each of the production sections.

3. The method according to claim 1, characterized in that The key characteristic peak detection is performed in the normalized acoustic spectrum corresponding to each of the production profiles to extract the characteristic peak segment corresponding to each of the production profiles, including: For the normalized acoustic spectrum corresponding to any of the production profiles, determine the data length and frequency range in the normalized acoustic spectrum, divide the data length by the frequency range to obtain the unit data density, determine the peak spacing constraint, peak width constraint and sensitivity window based on the unit data density, perform key feature peak detection in the normalized acoustic spectrum according to the set significance constraint, the peak spacing constraint, the peak width constraint and the sensitivity window, and extract the feature peak segment corresponding to the production profile.

4. The method according to claim 1, characterized in that: The denormalized peak segment corresponding to each production profile includes a starting frequency and an ending frequency; The step of determining a matching first peak segment in the anti-normalized peak segment corresponding to each production profile based on the set water phase response frequency band includes: For the anti-normalized peak segment corresponding to any of the production profiles, if the starting frequency and the ending frequency in the anti-normalized peak segment are determined to be within the water phase response frequency band, then the anti-normalized peak segment is determined to be the first peak segment.

5. The method according to claim 1, characterized in that After respectively performing denormalization on the characteristic peak segments corresponding to each of the production profiles to obtain the denormalized peak segments corresponding to each of the production profiles, the method further includes: Based on the set gas phase response frequency band, a matching second peak segment is determined in the inverse normalized peak segment corresponding to each of the production profiles, and the production profile corresponding to each of the second peak segments is determined as the gas production position.

6. The method according to claim 5, characterized in that Before determining the matching first peak segment in the denormalized peak segment corresponding to each production profile based on the set water phase response frequency band, the method includes: Based on the established fluid dynamics and acoustic coupling simulation model, the gas-water two-phase flow response characteristics are analyzed to determine the water phase response frequency band and the gas phase response frequency band.

7. The method according to claim 6, characterized in that The gas-water two-phase flow response characteristic analysis based on the established fluid dynamics and acoustic coupling simulation model to determine the water phase response frequency band and the gas phase response frequency band includes: Establishing a dynamic flow field model of gas-water two-phase flow in a gas well horizontal well, coupling the dynamic flow field model of gas-water two-phase flow in the gas well horizontal well with acoustic simulation software to construct a fluid dynamics and acoustic coupling simulation model; In the wellbore acoustic field area of ​​the fluid dynamics and acoustic coupling simulation model, four field points are arranged in sequence from the inlet to the outlet, and four different gas-water ratios are used as typical working conditions to perform flow field and acoustic field joint transient simulation, and the sound pressure level frequency domain data of each field point is extracted; The amplitude distribution and the spectrum response law are determined by comparing the frequency domain data of the sound pressure level of each field point, and the gas phase response frequency band and the water phase response frequency band are determined based on the spectrum response law.

8. A device for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves, characterized in that: include: A signal acquisition unit, used to acquire acoustic signals corresponding to a plurality of production profiles in the oil and gas wellbore through a distributed acoustic sensor arranged in the oil and gas wellbore; A signal processing unit, used to preprocess, time-frequency convert and normalize the acoustic signal corresponding to each of the production sections, to obtain a normalized acoustic spectrum corresponding to each of the production sections; A peak detection unit, used to perform key characteristic peak detection in the normalized acoustic spectrum corresponding to each of the production profiles, so as to extract a characteristic peak segment corresponding to each of the production profiles; A denormalization unit, used for respectively denormalizing the characteristic peak segment corresponding to each of the production profiles to obtain a denormalized peak segment corresponding to each of the production profiles; A peak matching unit, for determining a matching first peak segment in the denormalized peak segment corresponding to each of the production profiles based on a set water phase response frequency band; A water production positioning unit is used to determine the production profile corresponding to each of the first wave peak segments as a water production position.

9. A computer device, characterized in that: include: A memory and a processor, wherein the memory and the processor are communicatively connected to each other, the memory stores computer instructions, and the processor executes the method for locating the water production position of an oil and gas well based on distributed fiber optic acoustic waves as described in any one of claims 1 to 7 by executing the computer instructions.

10. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores computer instructions, and the computer instructions are used to enable a computer to execute the method for locating the water production position of an oil and gas well based on distributed optical fiber acoustic waves according to any one of claims 1 to 7.

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