A method and device for interpreting liquid production profile based on distributed optical fiber

Abstract

The present invention provides a method and device for interpreting a production profile based on distributed optical fiber. The method for interpreting a production profile based on distributed optical fiber corresponding to a single-phase flow production profile includes: generating an acoustic response benchmark when the liquid level in the wellbore is stationary according to multiple sensors of distributed optical fiber preset in the wellbore; acquiring distributed optical fiber response data of the corresponding layers according to the multiple sensors; and generating the production volume of the corresponding layers according to the acoustic response benchmark and the distributed optical fiber response data. The present invention not only has the technical advantages of distributed temperature sensing technology, but also can calculate a unique solution when processing and interpreting a multi-phase flow production profile, thereby realizing quantitative evaluation of the multi-phase flow production profile.

Description

Technical Field

[0001] The present application belongs to the field of oil and gas field development technology, in particular to the field of oil, gas and water well monitoring technology, and specifically relates to a method and device for interpreting a production liquid profile based on distributed optical fiber. Background Art

[0002] Distributed fiber optic monitoring technology and optical sensing technology are important components of intelligent oilfields. Due to their distributed monitoring characteristics, they are widely used in the dynamic monitoring of the production profile of oil, gas and water wells. At present, the distributed fiber optic sensing technology used in the quantitative measurement of the production profile mainly includes distributed temperature sensing technology (Distributed Temperature Sensing, DTS) and distributed acoustic sensing technology (Distributed fiber Acoustic Sensing, DAS). Among them, the distributed temperature sensing technology originated earlier, the interpretation method is more mature, and it has its unique technical advantages, which can be generally summarized as no delay, strong anti-interference ability, high measurement accuracy, strong adaptability to field conditions, etc. Although this technology has the above advantages, it still has the problem of multiple solutions when quantitatively evaluating the production profile of multiphase flow in the application process. Summary of the invention

[0003] One object of the present invention is to provide a method for interpreting abortion fluid profile based on distributed optical fiber, and the method has the following characteristics: it not only has the technical advantages of distributed temperature sensing technology, but can also calculate a unique solution when processing and interpreting abortion fluid profile of multiphase flow, thereby realizing quantitative evaluation of abortion fluid profile of multiphase flow.

[0004] Another object of the present invention is to provide a device for interpreting a liquid production profile based on distributed optical fiber. Another object of the present invention is to provide an electronic device, the electronic device comprising a memory and a processor, the memory storing a computer program, and the processor implementing the steps of the above-mentioned method for interpreting a liquid production profile based on distributed optical fiber when executing the computer program. Another object of the present invention is to provide a readable medium, on which a computer program is stored, and when the computer program is executed by the processor, the steps of the above-mentioned method for interpreting a liquid production profile based on distributed optical fiber are implemented.

[0005] In order to solve the technical problems in the background technology of this application, the present invention provides the following technical solutions:

[0006] In a first aspect, the present invention provides a method for interpreting abortion profiles based on distributed optical fibers, which is suitable for single-phase abortion profiles, and comprises:

[0007] Generate an acoustic response benchmark under the condition of static liquid level in the wellbore according to a plurality of distributed optical fiber sensors preset in the wellbore;

[0008] Acquire distributed optical fiber response data of the layers respectively corresponding to the multiple sensors;

[0009] The liquid production of the corresponding layer is generated according to the acoustic response benchmark and the distributed optical fiber response data.

[0010] In some embodiments of the present invention, the step of generating an acoustic response benchmark when the liquid level in the wellbore is stationary according to a plurality of sensors of distributed optical fibers preset in the wellbore includes:

[0011] Acquire background noise when the liquid level in the wellbore is static according to multiple distributed optical fiber sensors preset in the wellbore;

[0012] An acoustic response benchmark corresponding to the static condition of the liquid level in the wellbore is generated according to the background noise.

[0013] In some embodiments of the present invention, the distributed optical fiber response data includes: strain and echo signals.

[0014] In some embodiments of the present invention, the liquid production of the corresponding layer is generated according to the acoustic response benchmark and the distributed optical fiber response data, including:

[0015] Obtaining a total fluid production at a wellhead of the wellbore;

[0016] Generate a liquid production ratio of each layer relative to all layers according to the strain and echo signal corresponding to each layer, the acoustic response benchmark, and the strain and echo signals corresponding to all layers;

[0017] The liquid production of each layer is determined according to the total liquid production and the liquid production ratio.

[0018] In a second aspect, the present invention provides a method for interpreting a production fluid profile based on distributed optical fiber, which is suitable for a two-phase flow production fluid profile, comprising:

[0019] Sliding sampling is performed on distributed optical fiber response data acquired by a plurality of sensors of distributed optical fibers preset in the wellbore according to a preset sliding window;

[0020] Performing frequency-wave velocity transformation on the distributed optical fiber response data sampled in each sliding window to generate a plurality of transformation results;

[0021] Determine the liquid production ratio of each phase fluid corresponding to the multiple layers in the wellbore according to the multiple transformation results;

[0022] The fluid phase and liquid production corresponding to each layer are determined according to the liquid production ratio of each phase fluid corresponding to the multiple layers and the total liquid production of the wellbore obtained in advance.

[0023] In some embodiments of the present invention, the step of generating the sliding window includes:

[0024] The sliding window is generated according to a preset time sampling number and a preset space sampling number.

[0025] In some embodiments of the present invention, a method for interpreting a liquid production profile based on distributed optical fiber further includes:

[0026] Generate multiple frequency-wave velocity transformation diagrams according to the multiple transformation results; wherein the transformation results and the frequency-wave velocity transformation Figure 1 One to one correspondence;

[0027] The flow velocity of the fluid phase corresponding to each layer is determined according to the multiple frequency-wave velocity transformation diagrams.

[0028] In some embodiments of the present invention, determining the flow velocity of the fluid phase corresponding to each layer according to the multiple frequency-wave velocity transformation diagrams includes:

[0029] The flow velocity of the fluid phase corresponding to each layer is determined according to the shape of the upward wave and the shape of the downward wave in the multiple frequency-wave velocity transformation diagrams.

[0030] In a third aspect, the present invention provides a device for interpreting abortion profiles based on distributed optical fibers, which is suitable for single-phase abortion profiles, and comprises:

[0031] A response reference generation module, used to generate an acoustic response reference under a static liquid level condition in the wellbore according to a plurality of sensors of distributed optical fibers preset in the wellbore;

[0032] A response data acquisition module, used for acquiring distributed optical fiber response data of the layers respectively corresponding to the multiple sensors;

[0033] The liquid production generating module is used to generate the liquid production of the corresponding layer according to the acoustic response benchmark and the distributed optical fiber response data.

[0034] In some embodiments of the present invention, the response benchmark generation module includes:

[0035] A background noise acquisition unit, used for acquiring background noise in a wellbore under a static liquid level condition according to a plurality of sensors of distributed optical fibers preset in the wellbore;

[0036] A response reference generating unit is used to generate an acoustic response reference corresponding to the static condition of the liquid level in the wellbore according to the background noise.

[0037] In some embodiments of the present invention, the distributed optical fiber response data includes: strain and echo signals.

[0038] In some embodiments of the present invention, the liquid production generation module includes:

[0039] A total liquid production acquisition unit, used to acquire the total liquid production at the wellhead of the wellbore;

[0040] A liquid production ratio generating unit, used for generating a liquid production ratio of each layer relative to all layers according to the strain and echo signal corresponding to each layer, the acoustic response reference, and the strain and echo signal corresponding to all layers;

[0041] The liquid production generating unit is used to determine the liquid production of each layer according to the total liquid production and the liquid production ratio.

[0042] In a fourth aspect, the present invention provides a device for interpreting a production fluid profile based on distributed optical fiber, which is suitable for a two-phase flow production fluid profile, and the device comprises:

[0043] A response data sliding sampling module is used to perform sliding sampling on distributed optical fiber response data acquired by multiple sensors of distributed optical fibers preset in the wellbore according to a preset sliding window;

[0044] A transformation result generating module, used for performing frequency-wave velocity transformation on the cloth-type optical fiber response data sampled by each sliding window to generate a plurality of transformation results;

[0045] A liquid production ratio generating module, used for determining the liquid production ratio of each phase fluid corresponding to the multiple layers in the wellbore according to the multiple transformation results;

[0046] The fluid phase determination module is used to determine the fluid phase and liquid production corresponding to each layer according to the liquid production ratio of each phase fluid corresponding to the multiple layers and the total liquid production of the wellbore obtained in advance.

[0047] In some embodiments of the present invention, a liquid production profile interpretation device based on distributed optical fiber further includes:

[0048] A sliding window generation module, used to generate the sliding window, the sliding window generation module comprising:

[0049] The sliding window generating unit is used to generate the sliding window according to a preset time sampling number and a preset space sampling number.

[0050] In some embodiments of the present invention, a liquid production profile interpretation device based on distributed optical fiber further includes:

[0051] A transformation diagram generation module is used to generate multiple frequency-wave speed transformation diagrams according to the multiple transformation results; wherein the transformation results and the frequency-wave speed transformation Figure 1 One to one correspondence;

[0052] The flow velocity determination module is used to determine the flow velocity of the fluid phase corresponding to each layer according to the multiple frequency-wave velocity transformation diagrams.

[0053] In some embodiments of the present invention, the flow velocity determination module comprises:

[0054] The flow velocity determination unit is used to determine the flow velocity of the fluid phase corresponding to each layer according to the shape of the upgoing waves and the shape of the downgoing waves in the multiple frequency-wave velocity transformation diagrams.

[0055] In a fifth aspect, the present invention provides a computer program product, including a computer program / instruction, which, when executed by a processor, implements the steps of a method for interpreting a production profile based on distributed optical fiber.

[0056] In a sixth aspect, the present invention provides an electronic device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein when the processor executes the program, the steps of a method for interpreting a liquid production profile based on distributed optical fiber are implemented.

[0057] In a seventh aspect, the present invention provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the steps of a distributed optical fiber-based liquid production profile interpretation method.

[0058] From the above description, it can be seen that an embodiment of the present invention provides a method and device for interpreting a liquid production profile based on distributed optical fiber. The corresponding method for interpreting a liquid production profile based on distributed optical fiber (adaptable to single-phase flow liquid production profile) includes: first, generating an acoustic response benchmark under the condition of static liquid level in the wellbore according to multiple sensors of the distributed optical fiber preset in the wellbore; acquiring distributed optical fiber response data of the corresponding layers respectively according to the multiple sensors; and generating the liquid production of the corresponding layers respectively according to the acoustic response benchmark and the distributed optical fiber response data.

[0059] The corresponding distributed optical fiber-based fluid production profile interpretation method (suitable for two-phase flow fluid production profile) includes: first, sliding sampling of distributed optical fiber response data acquired by multiple sensors of distributed optical fibers preset in the wellbore according to a preset sliding window; then, frequency-wave velocity transformation of the distributed optical fiber response data sampled by each sliding window to generate multiple transformation results; determining the fluid production ratio of each phase fluid corresponding to multiple layers in the wellbore according to the multiple transformation results; finally, determining the fluid phase and liquid production corresponding to each layer according to the fluid production ratio of each phase fluid corresponding to the multiple layers and the total liquid production of the wellbore obtained in advance.

[0060] The method provided in the embodiment of the present invention can not only solve the problem of multiple solutions generated by distributed temperature sensing technology (DTS) when quantitatively evaluating the production profile of multiphase flow, but also can monitor the movement law of the fluid in the well in real time, realize the quantitative interpretation and evaluation of the production profile between each cluster, thereby optimizing and guiding the production allocation plan. BRIEF DESCRIPTION OF THE DRAWINGS

[0061] 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 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.

[0062] Figure 1 It is a schematic flow chart of a method for interpreting abortion fluid profile based on distributed optical fiber (suitable for abortion fluid profile of single-phase flow) in an embodiment of the present invention;

[0063] Figure 2 It is a flow chart of step 100 of a method for interpreting a liquid production profile based on distributed optical fiber in an embodiment of the present invention;

[0064] Figure 3 It is a flow chart of step 300 of the method for interpreting a liquid production profile based on distributed optical fiber in an embodiment of the present invention;

[0065] Figure 4 Schematic diagram of the process of the method for interpreting the production fluid profile based on distributed optical fiber (suitable for the production fluid profile of two-phase flow) in an embodiment of the present invention Figure 1 ;

[0066] Figure 5 Schematic diagram of the process of the method for interpreting the production fluid profile based on distributed optical fiber (suitable for the production fluid profile of two-phase flow) in an embodiment of the present invention Figure 2 ;

[0067] Figure 6 It is a flow chart of step E of the method for interpreting abortion fluid profile based on distributed optical fiber (suitable for biphasic flow abortion fluid profile) in an embodiment of the present invention;

[0068] Figure 7 Schematic diagram of the process of the method for interpreting the production fluid profile based on distributed optical fiber (suitable for the production fluid profile of two-phase flow) in an embodiment of the present invention Figure 3 ;

[0069] Figure 8 It is a flow chart of step G of the method for interpreting abortion fluid profile based on distributed optical fiber (suitable for biphasic flow abortion fluid profile) in an embodiment of the present invention;

[0070] Fig. 9 It is a schematic flow chart of a method for interpreting abortion fluid profile based on distributed optical fiber (suitable for abortion fluid profile of single-phase flow) in a specific embodiment of the present invention;

[0071] Fig.10 A mind map of a method for interpreting abortion fluid profile based on distributed optical fiber in a specific embodiment of the present invention (suitable for abortion fluid profile of single-phase flow);

[0072] Fig.11 It is a schematic diagram of the flow chart of the method for interpreting the abortion fluid profile based on distributed optical fiber (suitable for the abortion fluid profile of two-phase flow) in a specific embodiment of the present invention;

[0073] Fig.12 A mind map of a method for interpreting abortion fluid profile based on distributed optical fiber (suitable for biphasic flow abortion fluid profile) in a specific embodiment of the present invention;

[0074] Fig.13 It is a schematic diagram of a two-dimensional sliding window of DAS raw data in a specific implementation manner of the present invention;

[0075] Fig.14 It is a frequency-wave number diagram after the DAS raw data fk is transformed in a specific embodiment of the present invention;

[0076] Fig.15 It is a schematic diagram showing that the fluid velocity is the inverse of the slope of the downward wave in the fk diagram in a specific embodiment of the present invention;

[0077] Fig.16 It is a schematic diagram showing that the fluid velocity is the inverse of the slope of the upward wave in the fk diagram in a specific embodiment of the present invention;

[0078] Fig.17 It is a waterfall diagram of DAS strain rate response of shut-in test and three production regimes in a specific embodiment of the present invention;

[0079] Fig.18 It is a schematic diagram of the total production liquid production profile (full well section) in a specific implementation manner of the present invention;

[0080] Fig.19 It is a schematic diagram of the total production liquid production profile (screen tube section) in a specific embodiment of the present invention;

[0081] Fig. 20 It is a schematic diagram of the cross section (sieve tube section) of the oil-water two-phase abortion fluid in a specific embodiment of the present invention;

[0082] Fig.21 It is a block diagram of a production fluid profile interpretation device based on distributed optical fiber (suitable for single-phase flow production fluid profile) in an embodiment of the present invention;

[0083] Fig. 22is a block diagram of a response reference generation module 10 in an embodiment of the present invention;

[0084] Fig.23 is a block diagram of a liquid production generation module 30 in an embodiment of the present invention;

[0085] Fig.24 The block of the apparatus for explaining the production profile of the liquid based on the distributed optical fiber (suitable for the production profile of the two-phase flow) in the embodiment of the present invention is Figure 1 ;

[0086] Fig.25 The block of the apparatus for explaining the production profile of the liquid based on the distributed optical fiber (suitable for the production profile of the two-phase flow) in the embodiment of the present invention is Figure 2 ;

[0087] Fig.26 The block of the apparatus for explaining the production profile of the liquid based on the distributed optical fiber (suitable for the production profile of the two-phase flow) in the embodiment of the present invention is Figure 3 ;

[0088] Fig. 27 is a block diagram of the flow velocity determination module 12 in an embodiment of the present invention;

[0089] Fig.28 It is a schematic diagram of the structure of an electronic device in an embodiment of the present invention. DETAILED DESCRIPTION

[0090] In order to make the purpose, technical solution and advantages of the embodiments of the present invention clearer, the technical solution 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 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.

[0091] Those skilled in the art will appreciate that embodiments of the present invention may be provided as methods, systems, or computer program products. Therefore, the present invention may take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware. Moreover, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0092] It should be noted that the terms "including" and "having" in the specification and claims of the present application and the above-mentioned drawings and any variations thereof are intended to cover non-exclusive inclusions. For example, a process, method, system, product or device comprising a series of steps or units is not necessarily limited to those steps or units clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices. In the absence of conflict, the embodiments in the present application and the features in the embodiments may be combined with each other. The present application will be described in detail below with reference to the drawings and in combination with the embodiments.

[0093] The acquisition, storage, use, and processing of data in the technical solution of this application comply with the relevant provisions of laws and regulations.

[0094] The embodiment of the present invention provides a specific implementation method of a production fluid profile interpretation method based on distributed optical fiber (suitable for single-phase flow production fluid profile), see Figure 1 , the method specifically includes the following contents:

[0095] Step 100: Generate an acoustic response benchmark when the liquid level in the wellbore is static according to a plurality of sensors of distributed optical fibers preset in the wellbore;

[0096] Step 200: acquiring distributed optical fiber response data of the layers respectively corresponding to the multiple sensors;

[0097] Step 300: Generate the liquid production of the corresponding layer according to the acoustic response benchmark and the distributed optical fiber response data.

[0098] From the above description, it can be seen that the embodiment of the present invention provides a liquid production profile interpretation method based on distributed optical fiber (suitable for single-phase flow liquid production profile) including: first, generating an acoustic response benchmark under the condition of static liquid level in the wellbore according to multiple sensors of the distributed optical fiber preset in the wellbore; acquiring distributed optical fiber response data of the corresponding layers respectively according to the multiple sensors; and generating the liquid production of the corresponding layers respectively according to the acoustic response benchmark and the distributed optical fiber response data.

[0099] The method provided in the embodiment of the present invention can not only solve the problem of multiple solutions generated by distributed temperature sensing technology (DTS) when quantitatively evaluating the production profile of multiphase flow, but also can monitor the movement law of the fluid in the well in real time, realize the quantitative interpretation and evaluation of the production profile between each cluster, thereby optimizing and guiding the production allocation plan.

[0100] Regarding step 100, it should be explained that the stillness of the liquid level in the wellbore here refers to relative stillness, that is, the liquid level in the wellbore is relatively still before the well is opened (or in the well-closed state).

[0101] For step 200, preferably, the distributed optical fiber response data may include strain, strain rate or FBE frequency division data.

[0102] For step 300, it is necessary to know the total liquid production of the wellbore in advance, and subtract the seven corresponding acoustic response benchmarks from the distributed optical fiber response data at each layer. On this basis, the liquid production ratio corresponding to each layer is obtained, and finally the liquid production of each layer is obtained.

[0103] In some embodiments of the present invention, see Figure 2 , step 100 comprises:

[0104] Step 101: Acquire background noise when the liquid level in the wellbore is static using multiple sensors of distributed optical fibers preset in the wellbore;

[0105] Specifically, the energy or amplitude of the background noise is calculated by calculating the total energy of the signal acquired by the sensor and the average value of the frequency band energy.

[0106] Step 102: Generate an acoustic response benchmark corresponding to the static liquid level condition in the wellbore according to the background noise.

[0107] The acoustic response benchmark of the background noise is calculated using the frequency division data during the well shut-in period. Specifically, step 102 further includes the following steps:

[0108] According to the acoustic characteristics of the background noise, select an appropriate frequency weighting curve, such as A-weighting, C-weighting, etc. Multiply the frequency division data by the corresponding frequency weighting coefficient to take into account the human auditory characteristics at different frequencies. According to the spectral shape of the background noise data, perform equalization processing to flatten the spectrum and eliminate possible frequency deviations. Perform statistical analysis on the processed data, such as calculating the mean value, standard deviation, etc., to obtain the acoustic response benchmark of the background noise. These statistical indicators can reflect the overall level and range of variation of the background noise. Verify the accuracy and reliability of the calculated background noise acoustic response benchmark. It can be compared with existing background noise standards or reference data, or verified and corrected in actual applications.

[0109] In some embodiments of the present invention, the distributed optical fiber response data includes: strain and echo signal. Further, the echo signal can be FBE (Frequency Band Energy) frequency division data (frequency segment energy data obtained by analyzing and processing the acoustic signal using the characteristics of the optical fiber sensor). Specifically, the FBE frequency division data is used to analyze and monitor the spectral characteristics of the acoustic signal. The FBE frequency division data can be obtained in the following way: by frequency segmenting the echo signal and calculating the energy value of each frequency band to understand the distribution of the acoustic signal in different frequency bands.

[0110] In some embodiments of the present invention, see Figure 3 , step 300 comprises:

[0111] Step 301: Obtaining the total liquid production at the wellhead of the wellbore;

[0112] Step 302: Generate a liquid production ratio of each layer relative to all layers according to the strain and echo signal corresponding to each layer, the acoustic response reference, and the strain and echo signals corresponding to all layers;

[0113] Specifically, when processing the DAS data in the stable production stage, the benchmark value of the acoustic response benchmark is subtracted, the DAS response (strain, strain rate or FBE frequency division data) at the same depth is squared and converted into energy and then superimposed. The superimposed value of each depth is divided by the superimposed value of the entire production layer, which is the liquid production ratio of each liquid production depth or production layer. Finally, this ratio is multiplied by the total production measured at the wellhead to obtain the production of each liquid production depth or production layer.

[0114] In addition, it should be noted that in the case of multi-stage completion of horizontal wells, the depth of each production layer is known, and the starting and ending depths of the segment or cluster are directly used as the calculation interval during calculation. However, in the case of screen completion, when the depth and production of fluid production cannot be predicted, it is necessary to first calculate along each depth and then determine the depth interval with a production greater than zero or a larger production as the production layer.

[0115] The embodiment of the present invention provides a specific implementation method of a production fluid profile interpretation method based on distributed optical fiber (adapted to a two-phase flow production fluid profile), see Figure 4 , the method specifically includes the following contents:

[0116] Step A: Sliding sampling is performed on distributed optical fiber response data acquired by multiple sensors of distributed optical fibers preset in the wellbore according to a preset sliding window;

[0117] Step B: performing frequency-wave velocity transformation on the distributed optical fiber response data sampled in each sliding window to generate a plurality of transformation results;

[0118] Step C: determining the liquid production ratio of each phase fluid corresponding to the multiple layers in the wellbore according to the multiple transformation results;

[0119] Step D: Determine the fluid phase and liquid production corresponding to each layer according to the liquid production ratio of each phase fluid corresponding to the multiple layers and the total liquid production of the wellbore obtained in advance.

[0120] From the above description, it can be seen that the distributed optical fiber-based fluid production profile interpretation method (adapted to two-phase flow fluid production profile) provided in an embodiment of the present invention includes: first, sliding sampling of distributed optical fiber response data acquired by multiple sensors of the distributed optical fiber preset in the wellbore is performed according to a preset sliding window; then, frequency-wave velocity transformation is performed on the distributed optical fiber response data sampled by each sliding window to generate multiple transformation results; based on the multiple transformation results, the fluid production ratio of each phase of fluid corresponding to multiple layers in the wellbore is determined; finally, the fluid phase and liquid production corresponding to each layer are determined according to the liquid production ratio of each phase of fluid corresponding to the multiple layers and the total liquid production of the wellbore obtained in advance.

[0121] The method provided in the embodiment of the present invention can not only solve the problem of multiple solutions generated by distributed temperature sensing technology (DTS) when quantitatively evaluating the production profile of multiphase flow, but also can monitor the movement law of the fluid in the well in real time, realize the quantitative interpretation and evaluation of the production profile between each cluster, thereby optimizing and guiding the production allocation plan.

[0122] For step A, the frequency-wave number transform regards the signal as a change in time and space, and obtains the frequency-wave number domain representation by performing Fourier transform and spatial domain transform on the time domain signal. In the frequency-wave number domain, the frequency information of the signal is represented as the horizontal axis, and the wave number information is represented as the vertical axis. This is to better display the spectral characteristics and wave number distribution of the signal. The specific steps are as follows:

[0123] First, we start with a signal acquired in the time domain. For example, this could be a one-dimensional or two-dimensional time domain signal, representing fluctuations in time or space. We perform a Fourier transform on the time domain signal to convert it to the frequency domain. This can be done using methods such as the Continuous Fourier Transform (CFT) or the Discrete Fourier Transform (DFT).

[0124] Next, the Fourier transformed signal is transformed in the spatial domain to convert the signal to the wavenumber domain. This can be achieved by methods such as the two-dimensional Fourier transform (2DFT) or the two-dimensional fast Fourier transform (2DFFT). Finally, the fk domain representation is performed: in the frequency-wavenumber domain, the frequency information is represented as the horizontal axis and the wavenumber information is represented as the vertical axis. By plotting the amplitude or phase of the signal in the fk domain, a representation in the frequency-wavenumber domain can be obtained.

[0125] With respect to step B, the sliding window is two-dimensional, and is generated by a certain time sampling number and a certain space sampling number. The time sampling number and the space sampling number can be determined according to the number of sensors of the distributed optical fiber and the sampling rate.

[0126] For steps C and D, the acoustic wave velocity is calculated based on the consistent characteristics of acoustic waves and energy propagation, and the proportion of each phase fluid and the flow velocity are calculated based on the acoustic wave velocity. The velocity profile is established at repeated positions to explain the two-phase flow.

[0127] In some embodiments of the present invention, see Figure 5 , a method for interpreting a fluid production profile based on distributed optical fiber (suitable for a fluid production profile of two-phase flow), further comprising:

[0128] Step E: Generate the sliding window.

[0129] Next, see Figure 6 , step E comprises:

[0130] Step E1: Generate the sliding window according to a preset time sampling number and a preset space sampling number.

[0131] In some embodiments of the present invention, see Figure 7 , a method for interpreting a fluid production profile based on distributed optical fiber (suitable for a fluid production profile of two-phase flow), further comprising:

[0132] Step F: Generate multiple frequency-wave velocity transformation diagrams according to the multiple transformation results; wherein the transformation results and the frequency-wave velocity transformation Figure 1 One to one correspondence;

[0133] An fk transform map (image integral) is generated based on the distributed fiber response data within each two-dimensional sliding window.

[0134] Step G: Determine the flow velocity of the fluid phase corresponding to each layer according to the multiple frequency-wave velocity transformation diagrams.

[0135] In some embodiments of the present invention, see Figure 8 , step G comprises:

[0136] Step G1: Determine the flow velocity of the fluid phase corresponding to each layer according to the shape of the upgoing waves and the shape of the downgoing waves in the multiple frequency-wave velocity transformation diagrams.

[0137] In non-dispersive media, the speed of sound waves is independent of the frequency of sound waves, and the speed of energy transmission is consistent with the propagation of sound waves. This law is expressed as a straight line starting from the origin on the fk diagram; in dispersive media (wavelength is close to the diameter of medium particles), it is expressed as a curve starting from the origin on the fk diagram. In the steady production state, the DAS production profile logging can regard the wellbore, production string and fluid in the wellbore as non-dispersive media. Therefore, the fluid flow velocity can be calculated by the inverse of the slope of the upgoing wave and the downgoing wave on the fk diagram.

[0138] In a specific embodiment, the present invention also provides a specific embodiment of a method for interpreting abortion profile based on distributed optical fiber (suitable for single-phase flow abortion profile), see Fig. 9 as well as Fig.10 , specifically including the following contents.

[0139] Step S1: generating an acoustic response benchmark when the liquid level in the wellbore is stationary according to a plurality of sensors of distributed optical fibers preset in the wellbore;

[0140] Step S2: acquiring distributed optical fiber response data of the corresponding layers respectively according to the multiple sensors;

[0141] Step S3: Generate the liquid production of the corresponding layer according to the acoustic response benchmark and the distributed optical fiber response data.

[0142] See also Fig.10 In step S1 to step S3, firstly, random spike noise is removed from the DAS raw data, and then the frequency division energy data (1-10Hz) is extracted, and the sound intensity coordinate system is established and the sound intensity "waterfall chart" is drawn at the same time. The background noise baseline value is calculated using the frequency division data during the well shut-in period, and the background noise baseline value is subtracted from the frequency division data during the well opening period to highlight the production response, and the sound intensity curves of all time at different depths are calculated, the total well production data are accumulated, the total production or production proportion of different perforation clusters is calculated, the total production or production proportion of different fracturing stages is calculated, and a histogram of the total production or production proportion of all perforation clusters in all fracturing stages of the fracturing well is made, and the interpretation is completed by comprehensive calculation.

[0143] In a specific embodiment, the present invention also provides a specific embodiment of a method for interpreting a production fluid profile based on distributed optical fiber (adapted to a biphasic flow production fluid profile), see Fig.11 as well as Fig.12 , specifically including the following contents.

[0144] See also Fig.12 ,First, a certain number of time samples and a certain number of space samples are extracted (t, ,x=0 data are extracted), and a two-dimensional sliding window (2D FFT) is slid on the original DAS data (fk ,transformation), and the data in each two-dimensional sliding window generates an fk ,transformation graph (image integral), and the sound wave velocity is calculated through the consistent ,properties of sound wave and energy propagation, the proportion of each phase fluid and the flow velocity are calculated, and the velocity profile is ,repeatedly established, which can explain single-phase flow and multi-phase flow.

[0145] Step T1: preprocess the DAS data by fk transformation;

[0146] The fk transform is the frequency-wave velocity transform, which transforms the original DAS data in the time-distance domain into the frequency-wave velocity domain, thereby determining the propagation of sound wave energy with distance and the frequency attenuation of sound wave energy with distance. In practice, a certain number of time samples and a certain number of space samples are used as a two-dimensional sliding window ( Fig.13 The original DAS data is subjected to sliding fk transformation, and the data in each two-dimensional sliding window generates an fk transformation graph ( Fig.14 shown).

[0147] Step T2: Estimate the speed of sound in the fluid medium based on the fk data;

[0148] In non-dispersive media, the speed of sound waves and the frequency of sound waves are independent of each other, and the speed of energy transfer is consistent with the propagation of sound waves. This law is expressed on the fk diagram as a straight line starting from the origin; in dispersive media (the wavelength is close to the diameter of the medium particles), it is expressed on the fk diagram as a curve starting from the origin.

[0149] In the DAS production profile logging, under the steady production state, the wellbore, production string and the fluid in the wellbore can be regarded as non-dispersive media. The fluid flow velocity can be calculated from the inverse of the slope of the up-going wave and the down-going wave of the fk diagram ( Fig.15 as well as Fig.16 shown).

[0150] Step T3: Calculate the proportions and flow rates of different fluid phases.

[0151] After obtaining the sound velocities of different fluids, the formula for calculating the ratio of different fluid phases (taking oil and water as an example) is:

[0152]

[0153] where α o is the oil production (weight) ratio, and the coefficients A, B and C are calculated as follows:

[0154]

[0155]

[0156]

[0157] Among them, c m 、c o and c w are the sound wave velocities of mixed fluid, oil and water respectively, and ρ o and ρ w are the densities of oil and water, respectively, d is the diameter of the production string, t is the wall thickness of the production string, and E is the Young's modulus of the production string material.

[0158] It is worth noting that the above-mentioned production profile interpretation method based on DAS data can only interpret single-phase flow and two-phase flow, but not three-phase flow. The combined application of DAS and DTS can interpret three-phase flow.

[0159] Using the above-mentioned distributed optical fiber-based liquid production profile interpretation method applicable to single-phase flow and two-phase flow, the DAS data collected during the production of HWT98023 well on July 21, 2022, were processed and interpreted for the total production and oil and water production at each liquid production depth, and the total production liquid production profile and the oil-water two-phase flow liquid production profile were obtained.

[0160] As mentioned above, the DAS raw strain rate data during the shut-in test, open-well test production system 1 (slow-speed pump 6 times / minute), open-well test production system 2 (medium-speed pump 9 times / minute), open-well test production system 3 (high-speed pump 12 times / minute) and shut-in test were collected. The data has a high signal-to-noise ratio and can clearly distinguish the fluid DAS response of the entire well section without FBE frequency division processing.

[0161] Fig.17 This is the DAS data waterfall diagram. The left side shows the corresponding depth of the wellbore structure, and the right side shows the DAS response under the shut-in test and three production systems. The black solid line in the waterfall diagram is the data splicing line, and the white dotted line is the time dividing line between the shut-in test and different production systems. Fig.16 It can be seen that:

[0162] 1. Under the production conditions of system 1 (pump 6 times / minute), system 2 (pump 9 times / minute) and system 3 (pump 12 times / minute), the DAS waterfall chart is a process of liquid level falling and rising;

[0163] 2. The number of strokes in regime 1 (6 pumps / min), regime 2 (9 pumps / min) and regime 3 (12 pumps / min) increases, and the activity of the pumps accelerates, causing frequent fluctuations in the liquid level. Therefore, the DAS strain signal (density) increases, with an obvious response of fluid flowing to the wellhead.

[0164] As mentioned above, when the oil-water production ratio is not considered and only the total production of each liquid production depth or production layer is obtained, the single-phase flow DAS liquid production profile data processing and interpretation method can be applied.

[0165] like Fig.18 As shown in the figure, in this example, the DAS response benchmark value during the shut-in period is first established. The benchmark DAS response level of the screen section during the DAS shut-in period is between -10 and +10. The DAS data of the three production systems in the stable production stage are subtracted from the benchmark value, and then the DAS response (strain, strain rate or FBE frequency division data) at the same depth is squared and converted to energy, and then superimposed. The superimposed value of each depth is divided by the superimposed value of the entire production layer to obtain the liquid production ratio of each liquid production depth or production layer ( Fig.18 and Fig.19 ), and the ratio multiplied by the total production measured at the wellhead is the production of each production depth or production layer (Table 1). Note that the production profile of the well for the whole day is calculated based on the production profile of 3.5 hours during the DAS acquisition period.

[0166] Well HWT98023 was completed with a screen pipe. Theoretically, fluid can be produced from reservoirs in all depth intervals of the screen pipe section. However, the DAS cumulative strain reaches the maximum at 525.0-612.0 m and is much higher than other depth intervals, indicating that this depth interval is the main production layer, contributing about 88% of the production of the well.

[0167] Table 1 HWT98023 well production statistics of each layer

[0168]

[0169] Well HWT98023 was completed with screen pipes, and the produced fluids were oil and water. The DAS production profile monitoring showed that a total of 69.3 tons of fluid was produced on that day, including 39.5 tons of oil and 39.8 tons of water. The production proportions of oil and water were 57% and 43% respectively.

[0170] The data processing method of the two-phase flow abortion fluid profile is as described in the previous "two-phase flow abortion fluid profile". When applying this method, since the oil field only records the single-day production of the well and does not record the complete point-by-point or time-point production data, two assumptions need to be made:

[0171] 1. When using a sliding time window to perform fk transformation on DAS data, it is assumed that the wellhead production within the time window is constant;

[0172] 2. Since there is no production data corresponding to the 3.5 hours during the DAS data collection period, it is assumed that the liquid production for the 3.5 hours is 69.3 / 24*3.5=9.24t. The calculation result is used to estimate the oil and water production ratio of the well throughout the day.

[0173] The two-phase abortion fluid profile processing and interpretation method was applied, and the parameters involved in the formula (Formula-2) are shown in Table 2.

[0174] Table 2 Key parameters for calculating biphasic abortion fluid profile

[0175]

[0176] Applying the two-phase flow fluid production profile processing and interpretation method, the final obtained fluid production depth or production layer fluid production ratio is as follows: Fig. 20 As shown in the figure, the oil-water two-phase ratio multiplied by the total production measured at the wellhead is the oil-water production at each production depth or production layer (Table 3). Note that the table uses the production profile of 3.5 hours during the DAS acquisition period to estimate the production profile of the well for the whole day.

[0177] It can be seen from the figure that the main production layer (525.0~612.0m) determined by the total production liquid production profile contributes about 48% of the oil production of the well. At the same time, this layer is also the main water production layer, accounting for about 39% of the water production.

[0178] Table 3 Statistics of oil and water production in each production layer of HWT98023 well

[0179]

[0180] From the above description, it can be seen that the specific implementation of the present invention provides a method for interpreting a production fluid profile based on distributed optical fiber, which can monitor the movement law of the liquid in the well in real time and realize full-well section and all-weather monitoring of the wellbore integrity. The production data obtained is more real and reliable than traditional methods, and has reference significance for subsequent optimization and guidance of production allocation plans.

[0181] Based on the same inventive concept, the embodiments of the present application also provide a liquid production profile interpretation device based on distributed optical fiber, which can be used to implement the method described in the above embodiments, such as the following embodiments. Since the principle of solving the problem by the liquid production profile interpretation device based on distributed optical fiber is similar to that of the liquid production profile interpretation method based on distributed optical fiber, the implementation of the liquid production profile interpretation device based on distributed optical fiber can refer to the implementation of the liquid production profile interpretation method based on distributed optical fiber, and the repeated parts will not be repeated. As used below, the term "unit" or "module" can be a combination of software and / or hardware that implements the predetermined functions. Although the system described in the following embodiments is preferably implemented in software, the implementation of hardware, or a combination of software and hardware, is also possible and conceived.

[0182] The embodiment of the present invention provides a specific implementation of a distributed optical fiber-based liquid production profile interpretation device capable of implementing a distributed optical fiber-based liquid production profile interpretation method, wherein, see Fig.21 A distributed optical fiber-based abortion profile interpretation device (suitable for single-phase abortion profile) includes:

[0183] A response reference generation module 10 is used to generate an acoustic response reference when the liquid level in the wellbore is stationary according to a plurality of sensors of distributed optical fibers preset in the wellbore;

[0184] A response data acquisition module 20 is used to acquire distributed optical fiber response data of the corresponding layers according to the multiple sensors;

[0185] The liquid production generating module 30 is used to generate the liquid production of the corresponding layer according to the acoustic response benchmark and the distributed optical fiber response data.

[0186] In some embodiments of the present invention, see Fig. 22, the response benchmark generation module 10 comprises:

[0187] A background noise acquisition unit 10a is used to acquire background noise in a wellbore under a static liquid level condition according to a plurality of distributed optical fiber sensors preset in the wellbore;

[0188] The response reference generating unit 10b is used to generate an acoustic response reference corresponding to the static liquid level condition in the wellbore according to the background noise.

[0189] In some embodiments of the present invention, the distributed optical fiber response data includes: strain and echo signals.

[0190] In some embodiments of the present invention, see Fig.23 , the liquid production generation module 30 includes:

[0191] A total liquid production acquisition unit 30a, used to acquire the total liquid production at the wellhead of the wellbore;

[0192] The liquid production ratio generating unit 30b is used to generate the liquid production ratio of each layer relative to all layers according to the strain and echo signal corresponding to each layer, the acoustic response reference, and the strain and echo signal corresponding to all layers;

[0193] The liquid production generating unit 30c is used to determine the liquid production of each layer according to the total liquid production and the liquid production ratio.

[0194] The embodiment of the present invention also provides a specific implementation of a distributed optical fiber-based liquid production profile interpretation device capable of implementing a distributed optical fiber-based liquid production profile interpretation method, wherein, see Fig.24 A distributed optical fiber-based abortion profile interpretation device (suitable for biphasic flow abortion profile) includes:

[0195] The response data sliding sampling module 40 is used to perform sliding sampling on the distributed optical fiber response data acquired by multiple sensors of the distributed optical fiber preset in the wellbore according to a preset sliding window;

[0196] A transformation result generating module 50, for performing frequency-wave velocity transformation on the cloth-type optical fiber response data sampled by each sliding window to generate a plurality of transformation results;

[0197] A liquid production ratio generating module 60 is used to determine the liquid production ratio of each phase fluid corresponding to the multiple layers in the wellbore according to the multiple transformation results;

[0198] The fluid phase determination module 70 is used to determine the fluid phase and liquid production corresponding to each layer according to the liquid production ratio of each phase fluid corresponding to the multiple layers and the total liquid production of the wellbore obtained in advance.

[0199] In some embodiments of the present invention, see Fig.25 , a liquid production profile interpretation device based on distributed optical fiber also includes:

[0200] The sliding window generating module 80 is used to generate the sliding window. The sliding window generating module includes:

[0201] The sliding window generating unit 90 is used to generate the sliding window according to a preset time sampling number and a preset space sampling number.

[0202] In some embodiments of the present invention, see Fig.26 , a liquid production profile interpretation device based on distributed optical fiber also includes:

[0203] The transformation diagram generation module 11 is used to generate multiple frequency-wave speed transformation diagrams according to the multiple transformation results; wherein the transformation results and the frequency-wave speed transformation Figure 1 One to one correspondence;

[0204] The flow velocity determination module 12 is used to determine the flow velocity of the fluid phase corresponding to each layer according to the multiple frequency-wave velocity transformation diagrams.

[0205] In some embodiments of the present invention, see Fig. 27 , the flow velocity determination module 12 comprises:

[0206] The flow velocity determination unit 121 is used to determine the flow velocity of the fluid phase corresponding to each layer according to the shape of the upgoing waves and the shape of the downgoing waves in the multiple frequency-wave velocity transformation diagrams.

[0207] From the above description, it can be seen that an embodiment of the present invention provides a distributed optical fiber-based liquid production profile interpretation device, and the corresponding distributed optical fiber-based liquid production profile interpretation device (adaptable to single-phase flow liquid production profile) includes: a response reference generation module, which is used to generate an acoustic response reference under the condition of static liquid level in the wellbore according to multiple sensors of the distributed optical fiber preset in the wellbore; a response data acquisition module, which is used to acquire the distributed optical fiber response data of the corresponding layers according to the multiple sensors; a liquid production volume generation module, which is used to generate the liquid production of the corresponding layers according to the acoustic response reference and the distributed optical fiber response data.

[0208] The corresponding distributed optical fiber-based fluid production profile interpretation device (adapted to two-phase flow fluid production profile) includes: a response data sliding sampling module, which is used to perform sliding sampling on the distributed optical fiber response data acquired by multiple sensors of the distributed optical fiber preset in the wellbore according to a preset sliding window; a transformation result generation module, which is used to perform frequency-wave velocity transformation on the distributed optical fiber response data sampled by each sliding window to generate multiple transformation results; a fluid production ratio generation module, which is used to determine the fluid production ratio of each phase fluid corresponding to multiple layers in the wellbore according to multiple transformation results; a fluid phase determination module, which is used to determine the fluid phase and liquid production corresponding to each layer according to the fluid production ratio of each phase fluid corresponding to multiple layers and the total liquid production of the wellbore obtained in advance.

[0209] The device provided in the embodiment of the present invention not only has the technical advantages of the distributed temperature sensing technology, but can also calculate a unique solution when processing and interpreting the abortion fluid profile of multiphase flow, thereby realizing quantitative evaluation of the abortion fluid profile.

[0210] The embodiments of the present application also provide a specific implementation of an electronic device capable of implementing all steps in the method for interpreting a liquid production profile based on a distributed optical fiber in the above embodiments, see Fig.28 , electronic equipment specifically includes the following:

[0211] Processor (processor) 1201, memory (memory) 1202, communication interface (CommunicationsInterface) 1203 and bus 1204;

[0212] The processor 1201, the memory 1202, and the communication interface 1203 communicate with each other through the bus 1204; the communication interface 1203 is used to realize information transmission between the server device and the client device and other related devices;

[0213] The processor 1201 is used to call the computer program in the memory 1202. When the processor executes the computer program, all the steps in the liquid production profile interpretation method based on distributed optical fiber in the above embodiment are implemented. For example, when the processor executes the computer program, the following steps are implemented:

[0214] Step 100: Generate an acoustic response benchmark when the liquid level in the wellbore is static according to a plurality of sensors of distributed optical fibers preset in the wellbore;

[0215] Step 200: acquiring distributed optical fiber response data of the layers respectively corresponding to the multiple sensors;

[0216] Step 300: Generate the liquid production of the corresponding layer according to the acoustic response benchmark and the distributed optical fiber response data.

[0217] Step A: Sliding sampling is performed on distributed optical fiber response data acquired by multiple sensors of distributed optical fibers preset in the wellbore according to a preset sliding window;

[0218] Step B: performing frequency-wave velocity transformation on the distributed optical fiber response data sampled in each sliding window to generate a plurality of transformation results;

[0219] Step C: determining the liquid production ratio of each phase fluid corresponding to the multiple layers in the wellbore according to the multiple transformation results;

[0220] Step D: Determine the fluid phase and liquid production corresponding to each layer according to the liquid production ratio of each phase fluid corresponding to the multiple layers and the total liquid production of the wellbore obtained in advance.

[0221] The embodiments of the present application also provide a computer-readable storage medium capable of implementing all the steps in the method for interpreting a liquid production profile based on a distributed optical fiber in the above embodiment. The computer-readable storage medium stores a computer program. When the computer program is executed by a processor, all the steps in the method for interpreting a liquid production profile based on a distributed optical fiber in the above embodiment are implemented. For example, when the processor executes the computer program, the following steps are implemented:

[0222] Step 100: Generate an acoustic response benchmark when the liquid level in the wellbore is static according to a plurality of sensors of distributed optical fibers preset in the wellbore;

[0223] Step 200: acquiring distributed optical fiber response data of the layers respectively corresponding to the multiple sensors;

[0224] Step 300: Generate the liquid production of the corresponding layer according to the acoustic response benchmark and the distributed optical fiber response data.

[0225] Step A: Sliding sampling is performed on distributed optical fiber response data acquired by multiple sensors of distributed optical fibers preset in the wellbore according to a preset sliding window;

[0226] Step B: performing frequency-wave velocity transformation on the distributed optical fiber response data sampled in each sliding window to generate a plurality of transformation results;

[0227] Step C: determining the liquid production ratio of each phase fluid corresponding to the multiple layers in the wellbore according to the multiple transformation results;

[0228] Step D: Determine the fluid phase and liquid production corresponding to each layer according to the liquid production ratio of each phase fluid corresponding to the multiple layers and the total liquid production of the wellbore obtained in advance.

[0229] Each embodiment in this specification is described in a progressive manner, and the same or similar parts between the embodiments can be referred to each other, and each embodiment focuses on the differences from other embodiments. In particular, for the hardware + program embodiment, since it is basically similar to the method embodiment, the description is relatively simple, and the relevant parts can be referred to the partial description of the method embodiment.

[0230] The above is a description of a specific embodiment of the specification. Other embodiments are within the scope of the appended claims. In some cases, the actions or steps recorded in the claims can be performed in an order different from that in the embodiments and still achieve the desired results. In addition, the processes depicted in the drawings do not necessarily require the specific order or continuous order shown to achieve the desired results. In some embodiments, multitasking and parallel processing are also possible or may be advantageous.

[0231] Although the present application provides method operation steps such as embodiments or flow charts, more or fewer operation steps may be included based on conventional or non-creative labor. The order of steps listed in the embodiments is only one way of executing the order of many steps and does not represent the only execution order. When the actual device or client product is executed, it can be executed in the order of the method shown in the embodiments or the drawings or in parallel (for example, in a parallel processor or multi-threaded processing environment).

[0232] For the convenience of description, the above devices are described in various modules according to their functions. Of course, when implementing the embodiments of this specification, the functions of each module can be implemented in the same or more software and / or hardware, or the module implementing the same function can be implemented by a combination of multiple sub-modules or sub-units. 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. For example, 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.

[0233] Those skilled in the art also know that, in addition to implementing the controller in a purely computer-readable program code, the controller can be made to implement the same function in the form of logic gates, switches, application-specific integrated circuits, programmable logic controllers, and embedded microcontrollers by logically programming the method steps. Therefore, such a controller can be considered as a hardware component, and the devices for implementing various functions included therein can also be considered as structures within the hardware component. Or even, the devices for implementing various functions can be considered as both software modules for implementing the method and structures within the hardware component.

[0234] In a typical configuration, a computing device includes one or more processors (CPU), input / output interfaces, network interfaces, and memory.

[0235] The memory may include non-permanent storage in a computer-readable medium, random access memory (RAM) and / or non-volatile memory in the form of read-only memory (ROM) or flash RAM. The memory is an example of a computer-readable medium.

[0236] Each embodiment in this specification is described in a progressive manner, and the same and similar parts between the embodiments can be referred to each other, and each embodiment focuses on the differences from other embodiments. In particular, for the system embodiment, since it is basically similar to the method embodiment, the description is relatively simple, and the relevant parts can be referred to the partial description of the method embodiment. In the description of this specification, the description of the reference terms "one embodiment", "some embodiments", "example", "specific example", or "some examples" means that the specific features, structures, materials or characteristics described in conjunction with the embodiment or example are included in at least one embodiment or example of the embodiment of this specification. In this specification, the schematic representation of the above terms does not necessarily target the same embodiment or example. Moreover, the specific features, structures, materials or characteristics described can be combined in any one or more embodiments or examples in a suitable manner. In addition, in the absence of contradiction, a person skilled in the art can combine and combine the different embodiments or examples described in this specification and the features of different embodiments or examples.

[0237] The above is only an example of the embodiment of the present specification and is not intended to limit the embodiment of the present specification. For those skilled in the art, the embodiment of the present specification may have various changes and variations. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the embodiment of the present specification shall be included in the scope of the claims of the embodiment of the present specification.

Claims

1. A method for interpreting a liquid production profile based on distributed optical fiber, characterized in that: Adapted to single-phase abortion fluid profiles, including: Generate an acoustic response benchmark under the condition of static liquid level in the wellbore according to a plurality of distributed optical fiber sensors preset in the wellbore; Acquire distributed optical fiber response data of the layers respectively corresponding to the multiple sensors; Generating the liquid production of the corresponding layer respectively according to the acoustic response benchmark and the distributed optical fiber response data; The distributed optical fiber response data includes: strain and echo signal; the echo signal is FBE frequency division data, and the FBE frequency division data is used to analyze and monitor the spectrum characteristics of the acoustic wave signal; the FBE frequency division data is obtained by the following method, by dividing the echo signal into frequency segments and calculating the energy value of each frequency segment; Generating the liquid production of the corresponding layer according to the acoustic response benchmark and the distributed optical fiber response data respectively includes: Obtaining a total fluid production at a wellhead of the wellbore; Generate a liquid production ratio of each layer relative to all layers according to the strain and echo signal corresponding to each layer, the acoustic response benchmark, and the strain and echo signals corresponding to all layers; The liquid production of each layer is determined according to the total liquid production and the liquid production ratio, specifically: When processing the DAS data in the stable production stage, the reference value of the acoustic response reference is subtracted, the DAS response of the same depth is squared and converted to energy and then superimposed, and the superimposed value of each depth is divided by the superimposed value of the entire production layer to obtain the liquid production ratio of each liquid production depth or production layer, and finally the ratio is multiplied by the total production measured at the wellhead to obtain the production of each liquid production depth or production layer; the DAS response includes: the strain, strain rate or the FBE frequency division data; In the case of multi-stage completion of horizontal wells, the depth of each production layer is known, and the start and end depths of the segment or cluster are directly used as the calculation interval during calculation; In the case of screen completion, when the depth and production of fluid production cannot be predicted, it is necessary to first calculate along each depth and then determine the depth interval with a production greater than zero or a larger production as the producing layer.

2. The method for interpreting a production profile according to claim 1, characterized in that: The method of generating an acoustic response benchmark when the liquid level in the wellbore is static according to a plurality of distributed optical fiber sensors preset in the wellbore includes: Acquire background noise when the liquid level in the wellbore is static according to multiple distributed optical fiber sensors preset in the wellbore; An acoustic response benchmark corresponding to the static condition of the liquid level in the wellbore is generated according to the background noise.

3. A method for interpreting a production profile based on distributed optical fiber, characterized in that: Adapted to two-phase abortion fluid profiles, including: Sliding sampling is performed on distributed optical fiber response data acquired by a plurality of sensors of distributed optical fibers preset in the wellbore according to a preset sliding window; Performing frequency-wave velocity transformation on the distributed optical fiber response data sampled in each sliding window to generate a plurality of transformation results; Determine the liquid production ratio of each phase fluid corresponding to the multiple layers in the wellbore according to the multiple transformation results; Determine the fluid phase and liquid production corresponding to each layer according to the liquid production ratio of each phase fluid corresponding to the multiple layers and the total liquid production of the wellbore obtained in advance; Generating a plurality of frequency-wave velocity transformation diagrams according to the plurality of transformation results; wherein the transformation results correspond to the frequency-wave velocity transformation diagrams one by one; Determining the flow velocity of the fluid phase corresponding to each layer according to the multiple frequency-wave velocity transformation diagrams; Determining the flow velocity of the fluid phase corresponding to each layer according to the multiple frequency-wave velocity transformation diagrams includes: Determining the flow velocity of the fluid phase corresponding to each layer according to the shape of the upward wave and the shape of the downward wave in the multiple frequency-wave velocity transformation diagrams; Generating a plurality of frequency-wave speed transformation diagrams according to the plurality of transformation results, including: Generate an fk transformation map according to the cloth-type optical fiber response data in each two-dimensional sliding window, wherein the fk transformation map is an image integral; Determining the flow velocity of the fluid phase corresponding to each layer according to the shape of the upgoing waves and the shape of the downgoing waves in the multiple frequency-wave velocity transformation diagrams includes: In non-dispersive media, the acoustic wave velocity and acoustic wave frequency are independent of each other, and the energy transfer speed is consistent with the acoustic wave propagation. This law is expressed as a straight line starting from the origin on the fk diagram; in dispersive media, it is expressed as a curve starting from the origin on the fk diagram; in the DAS production fluid profile logging under steady production conditions, the wellbore, production tubing and fluid in the wellbore are regarded as non-dispersive media; the fluid flow velocity is calculated based on the inverse of the slope of the upgoing wave and the downgoing wave on the fk diagram.

4. The method for interpreting a production profile according to claim 3, characterized in that: The steps of generating the sliding window include: The sliding window is generated according to a preset time sampling number and a preset space sampling number.

5. A liquid production profile interpretation device based on distributed optical fiber, characterized in that: Adapted to single-phase abortion fluid profiles, including: A response reference generation module, used to generate an acoustic response reference under a static liquid level condition in the wellbore according to a plurality of sensors of distributed optical fibers preset in the wellbore; A response data acquisition module, used for acquiring distributed optical fiber response data of corresponding layers respectively according to the multiple sensors; A liquid production generating module, used to generate the liquid production of the corresponding layer according to the acoustic response benchmark and the distributed optical fiber response data; The distributed optical fiber response data includes: strain and echo signal; the echo signal is FBE frequency division data, and the FBE frequency division data is used to analyze and monitor the spectrum characteristics of the acoustic wave signal; the FBE frequency division data is obtained by the following method, by dividing the echo signal into frequency segments and calculating the energy value of each frequency segment; The liquid production generation module comprises: A total liquid production acquisition unit, used to acquire the total liquid production at the wellhead of the wellbore; A liquid production ratio generating unit, used for generating a liquid production ratio of each layer relative to all layers according to the strain and echo signal corresponding to each layer, the acoustic response reference, and the strain and echo signal corresponding to all layers; The liquid production generating unit is used to determine the liquid production of each layer according to the total liquid production and the liquid production ratio, specifically: When processing the DAS data in the stable production stage, the reference value of the acoustic response reference is subtracted, the DAS response of the same depth is squared and converted to energy and then superimposed, and the superimposed value of each depth is divided by the superimposed value of the entire production layer to obtain the liquid production ratio of each liquid production depth or production layer, and finally the ratio is multiplied by the total production measured at the wellhead to obtain the production of each liquid production depth or production layer; the DAS response includes: the strain, strain rate or the FBE frequency division data; In the case of multi-stage completion of horizontal wells, the depth of each production layer is known, and the start and end depths of the segment or cluster are directly used as the calculation interval during calculation; In the case of screen completion, when the depth and production of fluid production cannot be predicted, it is necessary to first calculate along each depth and then determine the depth interval with a production greater than zero or a larger production as the producing layer.

6. The liquid production profile interpretation device according to claim 5, characterized in that: The response benchmark generation module comprises: A background noise acquisition unit, used for acquiring background noise in a wellbore under a static liquid level condition according to a plurality of sensors of distributed optical fibers preset in the wellbore; A response reference generating unit is used to generate an acoustic response reference corresponding to the static condition of the liquid level in the wellbore according to the background noise.

7. A liquid production profile interpretation device based on distributed optical fiber, characterized in that: Adapted to two-phase abortion fluid profiles, including: A response data sliding sampling module is used to perform sliding sampling on distributed optical fiber response data acquired by multiple sensors of distributed optical fibers preset in the wellbore according to a preset sliding window; A transformation result generating module, used for performing frequency-wave velocity transformation on the cloth-type optical fiber response data sampled by each sliding window to generate a plurality of transformation results; A liquid production ratio generating module, used for determining the liquid production ratio of each phase fluid corresponding to the multiple layers in the wellbore according to the multiple transformation results; A fluid phase determination module, used to determine the fluid phase and liquid production corresponding to each layer according to the liquid production ratio of each phase fluid corresponding to the multiple layers and the total liquid production of the wellbore obtained in advance; A transformation diagram generation module, used to generate a plurality of frequency-wave velocity transformation diagrams according to the plurality of transformation results; wherein the transformation results correspond to the frequency-wave velocity transformation diagrams one by one; A flow velocity determination module, used to determine the flow velocity of the fluid phase corresponding to each layer according to the multiple frequency-wave velocity transformation diagrams; The flow velocity determination module comprises: A flow velocity determination unit, used to determine the flow velocity of the fluid phase corresponding to each layer according to the shape of the upgoing wave and the shape of the downgoing wave in the multiple frequency-wave velocity transformation diagrams; Generating a plurality of frequency-wave speed transformation diagrams according to the plurality of transformation results, including: Generate an fk transformation map according to the cloth-type optical fiber response data in each two-dimensional sliding window, wherein the fk transformation map is an image integral; Determining the flow velocity of the fluid phase corresponding to each layer according to the shape of the upgoing waves and the shape of the downgoing waves in the multiple frequency-wave velocity transformation diagrams includes: In non-dispersive media, the acoustic wave velocity and acoustic wave frequency are independent of each other, and the energy transfer speed is consistent with the acoustic wave propagation. This law is expressed as a straight line starting from the origin on the fk diagram; in dispersive media, it is expressed as a curve starting from the origin on the fk diagram; in the DAS production fluid profile logging under steady production conditions, the wellbore, production tubing and fluid in the wellbore are regarded as non-dispersive media; the fluid flow velocity is calculated based on the inverse of the slope of the upgoing wave and the downgoing wave on the fk diagram.

8. The liquid production profile interpretation device according to claim 7, characterized in that: Also includes: A sliding window generation module, used to generate the sliding window, the sliding window generation module comprising: The sliding window generating unit is used to generate the sliding window according to a preset time sampling number and a preset space sampling number.

9. A computer program product comprising a computer program / instructions, characterized in that When the computer program / instruction is executed by a processor, the steps of the method for interpreting a liquid production profile based on distributed optical fiber as described in any one of claims 1 to 4 are implemented.

10. An electronic device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that: When the processor executes the program, the steps of the method for interpreting a liquid production profile based on distributed optical fiber as described in any one of claims 1 to 4 are implemented.

11. A computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the steps of the method for interpreting a liquid production profile based on distributed optical fiber as described in any one of claims 1 to 4 are implemented.

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