A method and apparatus for generating seismic geologic data volumes

Abstract

This invention discloses a method and apparatus for generating seismic geological data volumes. The method includes: extracting seismic traces of a target stratigraphic segment from the seismic data volume; identifying seismic waveform feature points of a predetermined type within the seismic traces; deleting other sample points; aligning the seismic waveform feature points to corresponding positions on the geological trace time axis based on reflection time; converting the seismic waveform feature points into geological waveform marker points; performing lateral shifting of the geological waveform marker points according to a predetermined type correspondence and amplitude conversion relationship between the seismic waveform feature points and the geological waveform marker points to obtain a sequence of geological trace marker points; interpolating between adjacent marker points in the geological trace marker point sequence to obtain seismic geological trace waveform curves; and constructing a seismic geological data volume from all seismic geological trace waveform curves. This method generates a high-fidelity seismic geological data volume that simultaneously possesses seismic and sequence stratigraphic significance, making it more suitable for combined well-seismic analysis of thin reservoirs.

Description

Technical Field

[0001] This invention relates to the field of geophysical exploration and development technology, and in particular to a method and apparatus for generating seismic geological data volumes. Background Technology

[0002] Given the limited resolution of existing seismic data, conducting accurate seismic geological interpretation and detailed description of thin reservoirs (ΔH≤λ / 4) using conventional seismic data (waveform, phase, reflection phase axis, amplitude attributes, etc.) has always been a challenging problem. On the one hand, it is necessary to overcome the challenge of how to more effectively improve the seismic identification capability of thin reservoirs while assigning relatively isochronous sedimentological descriptive meaning, and to maximize the spatial interpretation potential and advantages of existing seismic data. On the other hand, the new methods and technologies for seismic data transformation adopted for thin-layer seismic sedimentological interpretation must be innovative, operable, intuitive, practical, and universally applicable.

[0003] Sicking (1982) and Chinese scholar Zeng Hongliu (1996-2004) successively studied and discussed the seismic sedimentological significance of 90° phase wavelets. In 2005, they were the first to publish an article in Geophysics demonstrating and proposing the idea and theory of 90° phase shift transformation of seismic data. Subsequently, this technology was applied in the description of thin reservoirs in several oilfields in China and achieved good application results under specific seismic geological conditions. The basic idea and implementation method of the current traditional 90° phase shift is as follows: when the time seismic signal cannot distinguish thin layers (ΔH≤λ / 4), the interface seismic reflection axis is aligned with the center of the thin reservoir through a 90° phase shift. This facilitates the full application of conventional seismic geological interpretation techniques and methods in the identification and prediction of thin reservoirs, while continuing to leverage the role of the seismic phase axis.

[0004] The first method is the 90° phase-shift wavelet technique based on traditional "convolution theory": By analyzing the phase of actual post-stack seismic data, performing zero-phase processing, and deconvolution, the reflection coefficient sequence of each seismic trace is first recovered. Then, appropriate ±90° or non-zero phase wavelets are selected and convolved with the reflection coefficient sequence of the post-stack seismic trace to create a synthetic seismic record. This achieves a ±90° rotation or phase shift of the phase of a single post-stack seismic trace, aligning the main lobe of the reflected wave with the center of the thin layer (converting the "interface" response of the reflection phase axis into a "layer" response). The 90° phase wavelets are symmetrically distributed around the top and bottom interfaces of the thin layer. Convolution is performed trace by trace, ultimately generating a new seismic data volume suitable for planar and profile seismic geological interpretation of thin layers (thin layer calibration, amplitude attribute slice analysis, etc.). The second method is the classic Hilbert transform: A complex-trace Hilbert transform is performed on the post-stack seismic data to obtain the imaginary part signal, directly achieving a 90° phase shift in the time domain of the original data, achieving the same conversion effect as the first method. In addition, the seismic trace integral method performs logarithmic filtering on the normalized relative wave impedance to decompose the composite wave into single waves and obtain a relatively stable trace integral relative impedance waveform data volume with prominent peaks, polarity reversal, and good ability to identify and interpret thin layers (with high longitudinal and transverse resolution). Summary of the Invention

[0005] The aforementioned traditional 90° phase shift method is a relatively intuitive and effective thin reservoir detection technique. However, the inventors have discovered that this traditional method still suffers from the following major problems: 1) Complex surface and subsurface geological and structural conditions lead to the time-varying, spatial-varying, and complex nature of seismic wavelets. It is extremely difficult to select an accurate, reasonable, and uniform 90° phase wavelet with a large time window. The sidelobes of the convolutional wavelet also reduce signal resolution. During the phase shift process, it is difficult to maintain dynamic consistency between the phase, time shift, waveform, and the original signal over a long time window. Even the reasonable, accurate, and effective selection of filtering factors in trace integral techniques and Hilbert transform methods all affect the original... 1) Issues with seismic data (frequency division) wavelet; 2) Using a uniform 90° phase wavelet to reprocess the synthetic records of each seismic trace in the post-stack seismic data (if the seismic data is non-zero phase, zero phase processing is required first). The processes of non-zero phase processing, deconvolution, and reconvolution will cause the superposition effect of time shift errors, which will change or destroy the original / post-stack seismic waveform structure, cross-axis / series phase, time-lapse, polarity reversal, and fidelity reduction, reducing the inheritance of the original high-resolution processed signal (such as the stratigraphic interfaces reflected by characteristic points such as reflection peaks, troughs, and zero-return). The location may drift uncertainly, and the amplitude, frequency, and polarity may also change. Even the peaks and valleys of the new seismic waveform in the 90° phase-shifted data volume, as well as the range and changes in the reflected energy, may not necessarily be seismic responses to actual strata changes, leading to strong ambiguity in subsequent interpretation and attribute analysis; 3) The amplitude of the imaginary part of the Hilbert rotation transform is calculated based on Euler's mathematical formula, which has mathematical significance. The main / side argument ratio is small, and for non-stationary, non-narrow-band seismic signals, the Hilbert transform will lose its physical meaning, resulting in poor signal fidelity; trace integral The peak value domain of the relative impedance curve in the method is only at the physical level; 4) The above-mentioned traditional 90° phase shift method itself cannot improve the resolution of the original signal. The actual thin layer resolution and interpretation effect after phase shift are strictly controlled by the type and complexity of the stratigraphic structure and whether the thin reservoir earthquake can respond effectively. In particular, the dominant frequency, bandwidth, wavelet stability, signal resolution and fidelity of conventional post-stack seismic data have a great impact. Moreover, the well control constraint is weak, the geological / sedimentary significance of geophysical transformation is unclear, and the applicable conditions of the method are harsh, and its practicality and application scope are obviously limited.

[0006] In order to at least partially solve the technical problems existing in the prior art, the inventors made this invention, which provides a method and apparatus for generating seismic geological data volume through specific implementation methods. This method generates a high-fidelity seismic geological data volume that has both seismic and sequence stratigraphic significance, is more suitable for fine description of thin reservoirs by well-seismic joint operations, and is more suitable for well-seismic joint operations.

[0007] In a first aspect, embodiments of the present invention provide a method for generating seismic geological data volumes, comprising:

[0008] Seismic traces of the target segment are extracted from the seismic data volume, seismic waveform feature points of a set type are identified in the seismic traces, and sample points other than the seismic waveform feature points in the seismic traces are deleted.

[0009] Based on the reflection time, the seismic waveform feature points are marked to the corresponding positions on the geological time axis, and the seismic waveform feature points are converted into geological waveform marker points;

[0010] According to the predetermined type correspondence and amplitude conversion relationship between seismic waveform feature points and geological waveform marker points, the lateral offset of the geological waveform marker points is completed to obtain the geological trace marker point sequence;

[0011] Interpolation is performed between two adjacent markers in the geological channel marker sequence to obtain seismic geological channels, and all seismic geological channels constitute the seismic geological data volume.

[0012] In a second aspect, embodiments of the present invention provide a seismic geological data volume generation apparatus, comprising:

[0013] The seismic waveform feature point identification module is used to extract seismic traces of a target segment from the seismic data volume, identify seismic waveform feature points of a set type in the seismic traces, and delete sample points other than the seismic waveform feature points in the seismic traces.

[0014] The geological waveform marker conversion module is used to mark the seismic waveform feature points to the corresponding positions on the geological time axis according to the reflection time, and convert the seismic waveform feature points into geological waveform marker points.

[0015] The geological tunnel marker sequence acquisition module is used to complete the lateral offset of the geological waveform markers according to the predetermined type correspondence and amplitude conversion relationship between seismic waveform feature points and geological waveform markers, and obtain the geological tunnel marker sequence.

[0016] The seismic geological data volume construction module is used to interpolate between two adjacent markers in the geological channel marker sequence to obtain seismic geological channels, and all seismic geological channels constitute the seismic geological data volume.

[0017] Thirdly, embodiments of the present invention provide a computer program product with the function of generating seismic geological data volumes, including a computer program / instruction, wherein the computer program / instruction, when executed by a processor, implements the above-mentioned method for generating seismic geological data volumes.

[0018] Fourthly, this disclosure provides a server, including: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the program to implement the above-described method for generating seismic geological data.

[0019] The beneficial effects of the above-described technical solutions provided in the embodiments of the present invention include at least the following:

[0020] (1) The method for generating seismic geological data volume provided in this embodiment of the invention extracts seismic traces of the target time-domain layer from the seismic data volume, identifies seismic waveform feature points in the seismic traces and retains their values, and deletes sample points and data other than feature points in the seismic traces; according to the reflection time, the seismic waveform feature points are marked to the corresponding positions on the time axis of the geological traces to convert the seismic waveform feature points into geological waveform marker points; according to the predetermined type correspondence and amplitude conversion relationship between the seismic waveform feature points and the geological waveform marker points, the left / right offset and positioning of the geological waveform marker points are completed to obtain the geological trace marker point sequence, and then the seismic geological trace waveform curve is obtained by interpolation, and the seismic geological traces are composed of all the seismic geological traces. Since the transformation process only performs position conversion, phase shift, and amplitude conversion calculations on the characteristic points of the seismic waveform, it inherits the processing results of the original seismic data volume, such as the distribution pattern of the main waveform characteristic points, the unchanged reflection time and position, and the consistency of frequency. At the same time, it does not involve complex wavelet problems (time-varying / space-varying), and avoids the problems of waveform structure complexity, distortion, and uncertain amplitude changes that may be caused by deconvolution and wavelet convolution of different phases or Hilbert transform. The transformation process has high fidelity.

[0021] (2) There are no special requirements for the resolution and main frequency of the seismic data volume, the applicable conditions are reduced, and the application scope is more universal.

[0022] (3) It can be applied to the transformation of post-stack 3D seismic data volumes to directly obtain seismic geological data volumes with a +90° phase shift and a +180° polarity reversal.

[0023] (4) The conversion is quick and efficient, the operation is simple and practical, and it is more suitable for the seismic geological dissection and rational analysis of the boundary of geological targets at a relatively small scale.

[0024] (5) Based on the established one-dimensional cycle / sequence model, the seismic trace waveform forward modeling is performed. The type correspondence between the seismic waveform feature points and the geological waveform marker points is determined according to the forward modeling results. Based on the "sequence-geophysical model forward modeling technology", the one-to-one response relationship between the seismic trace waveform feature points and the sequence marker points (seismic waveform ←→ geological waveform) is constructed, which interprets the role of sequence constraints and realizes the rapid conversion from geophysics to geology (seismic + sequence stratigraphy dual meaning). At the same time, it achieves the data transformation effect of 90° phase rotation + 180° polarity reversal. Before and after the application of the traditional 90° phase shift technology, the properties of the waveform feature points still remain at the geophysical level (seismic → seismic).

[0025] (6) The amplitude assignment method of geological waveform marker points is guided by the calculation ideas and approaches of "dynamic-elastic potential energy conservation and conversion principle" and "seismic waveform dynamic characteristic analysis" of the seismic wave propagation particles or mass elements. It adopts a characterization method that combines the inheritance of the amplitude value of the original signal feature points with the new connotation of the stratigraphic sequence. It completely avoids the influence of different phases and different frequencies of convolution wavelets, or the uncertainty of various filtering factors (trace integrals) obtained based on the complex time-varying and space-varying wavelets of the original signal on the uncertainty of the amplitude value of the new waveform feature points.

[0026] (7) The reservoir-sensitive logging curves of standard wells are used to perform overall stretching or compression correction on the initially generated seismic geological data volume, so that the new seismic geological channels are truly endowed with sequence-lithology-lithofamination connotations, rather than just remaining at the mathematical (Hilbert transform) or physical meaning, which is more conducive to the subsequent study of thin reservoir sedimentary characteristics of new attributes.

[0027] Other features and advantages of the invention will be set forth in the description which follows, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures particularly pointed out in the written description, claims, and drawings.

[0028] The technical solution of the present invention will be further described in detail below with reference to the accompanying drawings and embodiments. Attached Figure Description

[0029] The accompanying drawings are provided to further illustrate the invention and form part of the specification. They are used in conjunction with embodiments of the invention to explain the invention and do not constitute a limitation thereof. In the drawings:

[0030] Figure 1 This is a flowchart of the method for generating seismic geological data volumes in Embodiment 1 of the present invention;

[0031] Figure 2 This is a schematic diagram of the characteristic points of the seismic trace waveform in Embodiment 1 of the present invention;

[0032] Figure 3 This is a schematic diagram illustrating the forward modeling analysis of the relationship between the frequency-division convolutional waveform record of the cyclic model and the multi-cycle / multi-level sequence response in Embodiment 1 of the present invention;

[0033] Figure 4 This is a schematic diagram of the response modes of seismic waveform structure / feature points and sequence / cycle / stratigraphic model structure / feature points (interface) in Embodiment 1 of the present invention;

[0034] Figure 5 This is a schematic diagram of the method for assigning new attributes to geological feature points on a single-peak half-cycle waveform (peak + trough) of a seismic trace to a geological waveform in Embodiment 1 of the present invention.

[0035] Figure 6 This is a schematic diagram of the method for assigning new attributes to geological feature points on the seismic trace double-peak half-cycle waveform (peak / trough area) - geological waveform in Embodiment 1 of the present invention;

[0036] Figure 7 This is a schematic diagram of the method for assigning new attributes to geological feature points on the three-peak half-cycle waveform (peak region) of the seismic trace—geological waveform in Embodiment 1 of the present invention;

[0037] Figure 8 This is a schematic diagram of the method for assigning new attributes to geological feature points on the three-peak half-cycle waveform (trough area) of the seismic trace in Embodiment 1 of the present invention;

[0038] Figure 9 This is a comparison diagram of conventional seismic waveforms and converted geological waveforms in Embodiment 1 of the present invention;

[0039] Figure 10 This is a comparison diagram of the profiles of continuous seismic data (left) and 90° phase-shifted data (right) in Embodiment 2 of the present invention;

[0040] Figure 11 This is a comparison diagram of the SMI inversion profile effects of the top-band data (top) and the 90° phase-shifted top-band data (bottom) in Embodiment 2 of the present invention;

[0041] Figure 12 This is the identification diagram of the main target layer inversion profile in Embodiment 2 of the present invention based on the 90° phase shift geological data volume SMI inversion using extended frequency data;

[0042] Figure 13 This is a comparison diagram of the average impedance inversion slice planar sedimentary facies analysis of the overlay data (left) and the geological data (right) overlay with 90° phase shift in the overlay in Embodiment 2 of the present invention;

[0043] Figure 14 This is a geological inversion wellmap showing the reservoir characteristics of the inverted dilution well sedimentary facies in Embodiment 2 of the present invention.

[0044] Figure 15 This refers to the late stage (ES1) of the Shahejie Formation 1 in the Gaoyang Oilfield of the Bohai Bay Basin in Embodiment 2 of the present invention. x-1 +ES1 x-2 Highstand sedimentary models and sedimentary facies diagrams;

[0045] Figure 16 This is a comparison of the lithology / lithofacies plane prediction effects of new / old 90° phase shift data (P1t) for a certain block of gas reservoir in the Ordos Basin in Embodiment 2 of the present invention;

[0046] Figure 17 This is a well-match verification diagram of the new / old 90° phase shift method and the prediction results of thin reservoir characteristics of data volume attributes in Embodiment 2 of the present invention;

[0047] Figure 18 This is a schematic diagram of the structure of the seismic geological data volume generation device in an embodiment of the present invention. Detailed Implementation

[0048] Exemplary embodiments of the present disclosure will now be described in more detail with reference to the accompanying drawings. While exemplary embodiments of the present disclosure are shown in the drawings, it should be understood that the present disclosure may be implemented in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the disclosure to those skilled in the art.

[0049] To address the issues in existing technologies where conventional seismic data is unsuitable for thin reservoir prediction and where traditional seismic data exhibits poor fidelity with 90° phase shift transformation, this invention provides a method and apparatus for generating seismic geological data volumes. This method generates a high-fidelity seismic geological data volume that simultaneously possesses seismic and sequence stratigraphic significance, making it more suitable for combined well-seismic analysis of thin reservoirs.

[0050] Example 1

[0051] Embodiment 1 of the present invention provides a method for generating seismic geological data volumes, the process of which is as follows: Figure 1 As shown, it includes the following steps:

[0052] Step S11: Extract seismic traces of the target segment from the seismic data volume, identify seismic waveform feature points of the set type in the seismic traces, and delete sample points other than the seismic waveform feature points in the seismic traces.

[0053] Furthermore, time-domain seismic traces of the target layer are extracted from the seismic data volume, seismic waveform feature points of a set type are identified in the seismic traces and their values ​​are retained, while samples and data other than seismic waveform feature points in the seismic traces are deleted.

[0054] Seismic data volumes can be seismic data volumes that have undergone post-stack and frequency extension processing in sequence.

[0055] Based on the post-stack seismic data volume with good fidelity and inheriting zero-phase high-resolution processing, further new frequency extension processing is performed to broaden the effective frequency band of the signal and significantly improve the resolution.

[0056] Seismic traces of the target time-domain segment are extracted from the post-stacked frequency-copied seismic data volume. Seismic waveform feature points of a specified type are identified in each trace, and their reflection time and amplitude information are retained. Samples and data other than seismic waveform feature points in the traces are deleted.

[0057] Figure 2This is a schematic diagram of a seismic trace wave form record. The vertical line in the middle of the waveform is the reflection energy zero base line, and the left side represents the reflection time axis in milliseconds (ms). Seismic waveform feature points include the following three main types:

[0058] 1. Peaks or troughs.

[0059] Single wave peak P, complex wave peak P with the shortest reflection time among complex wave peaks, complex wave peak P with a non-short reflection time among complex wave peaks, single wave trough T, complex wave trough T with the shortest reflection time among complex wave troughs, complex wave trough T with a non-short reflection time among complex wave troughs.

[0060] In the same half-cycle waveform, multiple peaks or troughs are identified by their reflection times. The peak with the shortest reflection time is marked with the same symbol P (Peak) as a single peak, and the other one or two peaks with non-short reflection times are marked with italicized P. Similarly, the trough with the shortest reflection time is marked with the same symbol T (Trough) as a single trough, and the other one or two troughs with non-short reflection times are marked with italicized T.

[0061] The amplitude A (reflection amplitude) of the wave crest P or trough T is shown in [reference]. Figure 2 As shown in the diagram, the time from one single-wave trough to the next is one waveform cycle, and its length T* is the period. f* = 1 / T*, that is, the reciprocal of the period T* is the frequency f*.

[0062] 2. Return to zero.

[0063] Point B (Balance Point) includes the first amplitude zero-return point Bd, which is the zero-amplitude value in the process of amplitude changing from positive to negative along the direction of reflection time from small to large, and is also the deposition transition point (Balance deposition); and the second amplitude zero-return point Bf, which is the zero-amplitude value in the process of amplitude changing from negative to positive along the direction of reflection time from small to large, and is also the phase sequence transition point (Balance flooding).

[0064] III. Minimum or maximum value of half-cycle complex wave.

[0065] The negative amplitude maxima of a complex wave, which is the maximum negative amplitude in the negative half-cycle of the complex wave, is also the minimum absolute value of the amplitude. There can be two or one such maxima. Figure 2 The point marked as Ptn, where the suffix of n can be 1 or 2, represents a seismic waveform feature point of type complex wave with negative amplitude maximum, and is also the point of involution.

[0066] The minimum positive amplitude of a complex wave, that is, the minimum positive amplitude in the positive half-cycle of a complex wave, can be two or one. Figure 2 The suffix "Tpm" indicates that the suffix "m" can be either 1 or 2; it represents the seismic waveform characteristic point of the minimum positive amplitude of a complex wave, which is also the delamination point.

[0067] Step S12: Based on the reflection time, mark the seismic waveform feature points to the corresponding positions on the geological time axis to obtain the geological waveform marker points.

[0068] Specifically, the seismic trace zero-return line can be set as the geological trace time axis by default, and the seismic waveform feature points can be shifted to the corresponding positions on the time axis according to the reflection time, so as to convert the seismic waveform feature points into geological waveform marker points.

[0069] Alternatively, a new geological time sample can be established, and points with consistent reflection times can be identified on the geological time sample according to the reflection times of the seismic waveform feature points, serving as the geological waveform marker points corresponding to the seismic waveform feature points.

[0070] That is, the time position of the feature point remains unchanged, and the amplitude is zero. See [link / reference]. Figures 5-8 As shown, the conversion method is as follows:

[0071] P→B d *,P→V d *,T→B f *,T→V f *, B f →U D *, B d →D U *, Tpm→Tpm*, Ptn→Ptn*. For example, P→B d * Convert the seismic waveform feature point P, keeping its time position unchanged but setting its amplitude to zero, into a geological waveform marker point B. d * Figures 5-8 In the image, the left side shows the seismic waveform, and the right side shows the geological waveform.

[0072] The geological waveform markers obtained in step S12 are all located on the geological time axis and are marked with *.

[0073] Step S13: According to the predetermined type correspondence and amplitude conversion relationship between seismic waveform feature points and geological waveform marker points, complete the lateral offset of geological waveform marker points to obtain the geological trace marker point sequence.

[0074] Furthermore, the type correspondence between seismic waveform feature points and geological waveform marker points can be predetermined in the following way:

[0075] Seismic trace waveform forward modeling is performed based on a one-dimensional cycle / sequence model, and the type correspondence between seismic waveform feature points and geological waveform marker points is constructed based on the seismic forward modeling results.

[0076] See Figure 3 The diagram shows a forward modeling analysis of the frequency-division convolutional waveform record and the relationship between multi-cycle / multi-level sequence response. The selected impedance cycle model is the Cross theory cycle model, which includes 7 strata: ρ0v0, ρ1v1, ρ2v2, ρ3v3, ρ4v4, ρ5v5, and ρ6v6, forming 6 reflection interfaces R1, R2, R3, R4, R5, and R6. Their impedance relationships satisfy Z6(Z0)>Z5(Z1)>Z4(Z2)>Z3. Therefore, the first-order cycle ① is formed by the upper half of the cycle becoming coarser from bottom to top, and the lower half of the cycle becoming coarser from top to bottom; the second-order cycle ② and the third-order cycle ③ are both observed. Figure 3 As shown in the image.

[0077] By analyzing the frequency-division convolution waveforms and multi-phase cycle responses (20Hz(a), 30Hz(b), and 50Hz(c), the type correspondence between seismic waveform characteristic points and geological waveform marker points can be obtained. See [link to relevant documentation] for details. Figure 4 As shown:

[0078] The single-wave peak P of the seismic waveform characteristic point and the first amplitude zero-return point B of the geological waveform marker point d * also corresponds to the sedimentary transition point;

[0079] The complex wave peak P with the shortest reflection time among the complex wave peaks of the seismic waveform characteristic point and the first amplitude zero-return point B of the geological waveform marker point. d *correspond;

[0080] The complex wave peak P with a non-minimum reflection time in the complex wave peaks of the seismic waveform characteristic points and the maximum negative amplitude V of the complex wave at the geological waveform marker points. d *(Specifically, the maximum negative amplitude of the complex wave in the three-valley half-cycle waveform, and the V with a shorter reflection time) d * Marked as V d2 *, equivalent to the point of continuous de-integration; V with a relatively long reflection time d * Marked as V d1 *, equivalent to the deintegration point; the maximum negative amplitude of the complex wave in the double-valley half-cycle waveform is directly marked as V. d *)correspond, The maximum negative amplitude of the complex wave V d In amplitude shift The preceding label is V d * ;

[0081] The single-wave trough T of the seismic waveform characteristic point and the second amplitude zero-return point B of the geological waveform marker point f * also corresponds to the phase sequence transition point;

[0082] The complex wave trough T with the shortest reflection time in the complex wave trough of the seismic waveform characteristic point and the second amplitude zero-return point B of the geological waveform marker point. f *correspond;

[0083] The complex wave trough T with non-minimum reflection time in the complex wave trough of the seismic waveform characteristic point and the minimum positive amplitude V of the complex wave at the geological waveform marker point. f *(Specifically, the minimum positive amplitude of the complex wave in the three-peak half-cycle waveform, and the V with a shorter reflection time) f * Marked as V f1 *, equivalent to the point of continuous accumulation; V with a longer reflection time f * Marked as V f2 *, equivalent to the point of action of the product; the minimum value of the complex wave positive amplitude in the double-peaked half-cycle waveform is directly marked as... V f * )correspond, Minimum of positive amplitude of complex wave V f In amplitude shift The preceding label is V f * ;

[0084] The second amplitude zero-return point B of the seismic waveform characteristic points f (The point where the amplitude returns to zero during the process of amplitude changing from negative to positive, which is also the phase sequence transition point) and the complex wave peak with the longest reflection time among the single wave peak or complex wave peak of the geological waveform marker point U. D Corresponding to, U D Marked before amplitude offset

[0085] The first amplitude zero-return point B of the seismic waveform characteristic points d (The point where the amplitude returns to zero during the process of amplitude changing from positive to negative, which is also the point of sedimentary transition) and the complex wave trough with the largest relative reflection time among the single-wave or complex-wave troughs of the geological waveform marker point, D. U Corresponding to D U Marked before amplitude offset

[0086] The maximum negative amplitude of the complex wave at the seismic waveform feature point, Tpm (specifically, Tpm with a shorter reflection time is labeled Tpm1, and Tpm with a longer reflection time is labeled Tpm2), and the complex wave peak with a non-maximum relative reflection time, Psm, at the geological waveform marker point (specifically, Psm with a shorter reflection time is labeled Psm1, and Psm with a longer reflection time is labeled Psm2). Psm is labeled as Tp* before amplitude shift.

[0087] The minimum positive amplitude of the complex wave at the seismic waveform feature point is Ptn (specifically, Ptn with a smaller reflection time is labeled Ptn1, and Ptn with a larger reflection time is labeled Ptn2). The complex wave valley with the non-maximum relative reflection time in the complex wave valley of the geological waveform marker point is Rsn (specifically, Rsn with a smaller reflection time is labeled Rsn1, and Rsn with a larger reflection time is labeled Rsn2). Rsn is labeled Ptn* before amplitude shift.

[0088] Furthermore, the amplitude conversion relationship between seismic waveform feature points and geological waveform marker points can be predetermined in the following way:

[0089] By utilizing the principles of conservation and conversion of kinetic and elastic potential energy of particle vibration during seismic wave propagation, combined with the analysis of seismic waveform dynamics characteristics and the seismic forward modeling results of a one-dimensional cyclic model, the amplitude conversion relationship between characteristic points of seismic waveforms and marker points of geological waveforms is determined.

[0090] In some embodiments, according to the predetermined type correspondence between seismic waveform feature points and geological waveform marker points, the type of geological waveform marker points is determined based on the type of seismic waveform feature points, and the lateral offset direction is determined based on the type of geological waveform marker points, that is, whether the amplitude of the marker point is offset to the right or to the left; according to the predetermined amplitude conversion relationship between seismic waveform feature points and geological waveform marker points, that is, the amplitude calculation formula, the absolute value of the amplitude of the geological waveform marker points is assigned; the offset of the geological waveform marker points is completed based on the determined lateral offset direction and the absolute value of the amplitude, that is, the positioning of the geological waveform marker points, and a geological trace marker point sequence is obtained.

[0091] If the geological waveform marker is of type Bd (depositional transition point, marked as Bd* before amplitude shift) or Bf (phase sequence transition point, marked as Bf* before amplitude shift), the geological waveform marker will not shift (the shift amount is zero).

[0092] If the geological waveform marker point is of type U, which is a complex wave peak with the longest reflection time among single-wave peaks and complex wave peaks... D (Amplitude offset is marked as U) D *) If the relative reflection time of the complex wave peak is not the largest (marked as Tpm* before amplitude shift) or the positive amplitude minimum value of the complex wave is Vf (marked as Vf* before amplitude shift), the amplitude assignment of the geological waveform marker point is shifted and positioned in the positive direction (to the right).

[0093] If the geological waveform marker point is a single-wave trough or a complex-wave trough with the longest relative reflection time (D) U (Amplitude offset is marked as D) U*) If the relative reflection time of the complex wave trough is not the largest (marked as Pt* before amplitude shift) or the negative amplitude maximum value of the complex wave is Vd (marked as Vd* before amplitude shift), the amplitude assignment of the geological waveform marker point is shifted and positioned in the negative direction (to the left).

[0094] The calculation of the amplitude offset of each type of geological waveform marker point will be explained in detail later.

[0095] The left and right movement of the geological waveform marker points is to facilitate matching and consistency comparison analysis with the well logging reservoir and sequence identification and division on the well curves (SP, GR, AC), so as to achieve "intuitive matching of well seismic dimensions".

[0096] Step S14: Interpolate between two adjacent markers in the geological trace marker sequence to obtain seismic geological traces, and the seismic geological data volume is composed of all seismic geological traces.

[0097] Specifically, the earthquake geological channel refers to the waveform curve of the earthquake geological channel.

[0098] Furthermore, cosine interpolation can be used to interpolate between adjacent marker points in the geological trace marker sequence according to the post-stack sampling interval. This reconstructs a vertically complete and continuous seismic geological waveform / curve trace with both seismic and sequence significance.

[0099] The seismic geological data volume generation method provided in Embodiment 1 of the present invention extracts seismic traces of the target time-domain layer from the seismic data volume, identifies seismic waveform feature points in the seismic traces and retains their values, and deletes sample points and data other than feature points in the seismic traces; according to the reflection time, the seismic waveform feature points are marked to the corresponding positions on the time axis of the geological traces to convert the seismic waveform feature points into geological waveform marker points; according to the predetermined type correspondence and amplitude conversion relationship between the seismic waveform feature points and the geological waveform marker points, the left / right offset and positioning of the geological waveform marker points are completed to obtain the geological trace marker point sequence, and then the seismic geological trace waveform curve is obtained by interpolation, and the seismic geological traces constitute the seismic geological data volume. Since the transformation process only performs position conversion, phase shift, and amplitude conversion calculations on the characteristic points of the seismic waveform, it inherits the processing results of the original seismic data volume, such as the distribution pattern of the main waveform characteristic points, the unchanged reflection time and position, and the consistency of frequency. At the same time, it does not involve complex wavelet problems (time-varying / space-varying), and avoids the problems of waveform structure complexity, distortion, and uncertain amplitude changes that may be caused by deconvolution and wavelet convolution of different phases or Hilbert transform. The transformation process has high fidelity.

[0100] There are no special requirements for the resolution and dominant frequency of seismic data volumes, the applicable conditions are reduced, and the application scope is more universal.

[0101] It can be applied to the transformation of post-stack 3D seismic data volumes, directly obtaining seismic geological data volumes with a +90° phase shift and a +180° polarity reversal.

[0102] The conversion is quick and efficient, the operation is simple and the practicality is strong. It is more suitable for the seismic geological dissection and rational analysis of relatively small-scale reservoir profiles and geological target boundaries.

[0103] Based on a one-dimensional cycle / sequence model, forward modeling of seismic trace waveforms is performed. The type correspondence between seismic waveform feature points and geological waveform marker points is determined according to the forward modeling results. That is, the "sequence-geophysical model forward modeling technology" is used to construct a one-to-one response relationship between seismic trace waveform feature points and sequence boundary marker points (seismic waveform ←→ geological waveform), which interprets the role of sequence constraints and realizes rapid geophysical to geological conversion (seismic + sequence stratigraphy dual meaning). At the same time, it achieves the data transformation effect of 90° phase rotation + 180° polarity reversal. However, before and after the application of traditional 90° phase shift technology, the properties of waveform feature points still remain at the geophysical level (seismic → seismic).

[0104] The amplitude assignment method for geological waveform marker points is guided by the calculation ideas and approaches of "dynamic-elastic potential energy conservation and conversion principle" and "seismic waveform dynamic characteristic analysis" of seismic wave propagation particles or mass elements. It adopts a characterization method that combines the inheritance of the amplitude value of the original signal feature points with the new connotation of the stratigraphic sequence. It completely avoids the influence of different phases and frequencies of convolutional wavelets, or the uncertainty of various filtering factors (trace integrals) obtained based on the complex time-varying and spatially varying wavelets of the original signal on the uncertainty of the amplitude value of the new waveform feature points.

[0105] The calculation of the amplitude offset of each type of geological waveform marker point in step S13 above can be divided into the following three cases:

[0106] 1. A method for assigning the absolute amplitude of geological waveform marker points based on a single waveform:

[0107] ①B d *:A Bd* =0, position remains unchanged.

[0108] ②B f *:A Bf* =0, position remains unchanged.

[0109] See Figure 5 The diagram shows the calculation method for the amplitude offset of geological marker points on the geological waveform corresponding to the single-peak / single-valley half-cycle waveform (peak + trough) of the seismic trace. Geological waveform marker point B. d * and B f The amplitude offset of * is 0, meaning that these two types of markers do not shift.

[0110] ③U D* AU D =(A i-1 +|A j |) / 2,U D * Move the point horizontally to the right → new position U D .

[0111] If the geological waveform marker point is of type single wave peak U D * The absolute amplitude of the marker point is determined by half the sum of the absolute amplitude of the next feature point of the seismic waveform feature point corresponding to the marker point and the absolute amplitude of the previous feature point.

[0112] Specifically, the next feature point refers to the adjacent feature point with a longer reflection time, and is simply referred to as the next feature point; the previous feature point refers to the adjacent feature point with a shorter reflection time, and is simply referred to as the previous feature point.

[0113] Figure 5 In the middle, the formula for calculating the absolute value of the amplitude of the next single wave peak is: AU D =(A i +|A j+1 |) / 2.

[0114] ④D U * AD U =(A i +|A j |) / 2,D U * Move the point horizontally to the left → new position D u .

[0115] If the type of the geological waveform marker point is a single-wave valley DU*, the absolute amplitude value of the marker point is determined by half the sum of the absolute amplitude value of the next feature point of the seismic waveform feature point corresponding to the marker point and the absolute amplitude value of the previous feature point.

[0116] 2. A method for assigning the absolute value of the amplitude of geological waveform marker points based on bimodal / bivalve semi-circular complex waveforms:

[0117] See Figure 6 As shown, four new markers have appeared (Tpm*, Ptn*, V). d * and V f *) and two markers with changing properties (U) D * D U * The absolute amplitude values ​​of other marker points are calculated in the same way as the corresponding marker points in a single wave. The absolute amplitude values ​​of the four newly added characteristic marker points and the two marker points with changed properties are calculated as follows:

[0118] ①Tpm*:A psm =(|A j+1 |+|A j |) / 2;Tpm* point moves horizontally to the right → new position Psm.

[0119] If the geological waveform marker is a complex wave peak Tpm* in a double-peak half-cycle waveform where the reflection time is not the largest, then half of the sum of the absolute amplitude of the next feature point of the seismic waveform feature point corresponding to the marker and the absolute amplitude of the previous feature point is determined as the absolute amplitude of the marker.

[0120] ②Ptn*:A Rsn =(A i +A i+1 ) / 2; Ptn* point moves horizontally to the left → new position Rsn.

[0121] If the geological waveform marker point is a complex wave valley Ptn* in a double-valley half-cycle waveform where the relative reflection time is not the largest, then half of the sum of the absolute amplitude of the next feature point of the seismic waveform feature point corresponding to the marker point and the absolute amplitude of the previous feature point is determined as the absolute amplitude of the marker point.

[0122] ③U D * AU D =(|A j+1 |+|A j |) / 2,U D * Move the point horizontally to the right → new position U D .

[0123] If the geological waveform marker point is a complex wave peak U with the longest reflection time in a bimodal half-cycle waveform... D * The absolute amplitude of the marker point is determined by half the sum of the absolute amplitude of the next feature point of the seismic waveform feature point corresponding to the marker point and the absolute amplitude of the previous feature point.

[0124] ④D U * AD U =(A i+1 +|A j+2 |) / 2,D U * Move the point horizontally to the left → new position D u .

[0125] If the geological waveform marker point is of type D, which is the complex wave valley with the longest reflection time in a double-valley half-cycle waveform... U * The absolute amplitude of the marker point is determined by half the sum of the absolute amplitude of the next feature point of the seismic waveform feature point corresponding to the marker point and the absolute amplitude of the previous feature point.

[0126] ⑤V d *:AV d =(A Rsn +|AD u |) / 4;V d * Move the point horizontally to the left → New position V d .

[0127] V d *The point is perpendicular to the time axis Ptn* and D. U * The midpoint between the two points.

[0128] If the geological waveform marker point is the maximum negative amplitude V in the double-valley half-cycle waveform d * The absolute amplitude of the marker point is determined by taking one-quarter of the sum of the absolute amplitude of the next marker point and the absolute amplitude of the previous marker point.

[0129] ⑥V f *:AV f =(A psm +AU D ) / 4;V f * Move the point to the right → New position V f .

[0130] V f *The point is vertically upward on the time axis Tpm* and U D * The midpoint between the two points.

[0131] If the geological waveform marker point is a bimodal half-cycle waveform with a minimum positive amplitude V f * The absolute amplitude of the marker point is determined by taking one-quarter of the sum of the absolute amplitude of the next marker point and the absolute amplitude of the previous marker point.

[0132] 3. A method for assigning the absolute amplitude of geological waveform marker points based on the three-valley half-cycle waveform (see...) Figure 7 As shown):

[0133] ①Ptn*: Point Ptn* moves horizontally to the left → new position Rsn.

[0134] Specifically, Ptn1*: A Rsn1 =(A i +A i+1 ) / 2; Ptn1* point moves horizontally to the left → new position Rsn1; Ptn2*: A Rsn2 =(A i+1 +A i+2 ) / 2; Ptn2* point moves horizontally to the left → new position Rsn2.

[0135] If the geological waveform marker point is a complex wave valley Ptn* in a three-valley half-cycle waveform where the reflection time is not the largest, then half of the sum of the absolute amplitude of the next feature point of the seismic waveform feature point corresponding to the marker point and the absolute amplitude of the previous feature point is determined as the absolute amplitude of the marker point.

[0136] ②D U * AD U =(A i+2 +|A j+2 |) / 2,D U * Move the point horizontally to the left → new position D u .

[0137] If the geological waveform marker point is of type D, which is the complex wave trough with the longest reflection time in the three-trough half-cycle waveform... U * The absolute amplitude of the marker point is determined by half the sum of the absolute amplitude of the next feature point of the seismic waveform feature point corresponding to the marker point and the absolute amplitude of the previous feature point.

[0138] ③V d2 *:AV d2 =(A Rsn1 +A Rsn2 ) / 4;V d2 * Move the point horizontally to the left → New position V d2 .

[0139] If the geological waveform marker point is of type V, which is a negative amplitude maximum value of the three-valley half-cycle waveform with a short reflection time... d * The absolute amplitude of the marker point is determined by taking one-quarter of the sum of the absolute amplitude of the next marker point and the absolute amplitude of the previous marker point.

[0140] ④V d1 *:AV d1 =(AU) D +A Rsn2 ) / 4;V d1 * Move the point horizontally to the left → New position V d1 .

[0141] If the geological waveform marker point is of type V, which is a negative amplitude maximum value of the three-valley half-cycle waveform with a relatively long reflection time... d * The absolute amplitude of the marker point is determined by taking one-quarter of the sum of the absolute amplitude of the next marker point and the absolute amplitude of the previous marker point.

[0142] 4. A method for assigning the absolute amplitude of geological waveform marker points based on three-peak half-cycle waveforms (see...) Figure 8 As shown):

[0143] ①Tpm*: Move the Tpm* point horizontally to the right → new position Psm.

[0144] Specifically, Tpm1*: A psm1 =(|A j-1 |+|A j |) / 2;Tpm1* point moves horizontally to the right → new position Psm1. Tpm2*: A psm2 =(|A j |+|A j+1 |) / 2;Tpm2* point moves horizontally to the right → new position Psm2.

[0145] If the geological waveform marker is a complex wave peak Tp* in a three-peak half-cycle waveform with a non-maximum reflection time, the absolute amplitude of the marker is determined by half the sum of the absolute amplitude of the next feature point of the seismic waveform feature point and the absolute amplitude of the previous feature point.

[0146] ②U D * AU D =(|A j+1 |+|A i |) / 2,U D * Move the point horizontally to the right → new position U D .

[0147] If the geological waveform marker point is the complex wave peak U with the longest reflection time in a three-peak half-cycle waveform... D * The absolute amplitude of the marker point is determined by half the sum of the absolute amplitude of the next feature point of the seismic waveform feature point corresponding to the marker point and the absolute amplitude of the previous feature point.

[0148] ③V f1 *:AV f1 =(A psm1 +A psm2 ) / 4;V f1 * Move the point to the right → New position V f1 .

[0149] If the geological waveform marker point is a three-peaked half-cycle waveform with a short reflection time, the minimum positive amplitude V f * The absolute amplitude of the marker point is determined by taking one-quarter of the sum of the absolute amplitude of the next marker point and the absolute amplitude of the previous marker point.

[0150] ④V f2 *:AV f2 =(AU) D +A psm2 ) / 4;V f2 * Move the point to the right → New position V f2 .

[0151] If the geological waveform marker point is a three-peaked half-cycle waveform with a relatively long reflection time, the minimum positive amplitude V f * The absolute amplitude of the marker point is determined by taking one-quarter of the sum of the absolute amplitude of the next marker point and the absolute amplitude of the previous marker point.

[0152] The absolute amplitude A of each geological marker point in the vertical continuous calculation is assigned sequence meaning and transferred to the corresponding new feature point position on the geological tunnel waveform curve.

[0153] By calculating each geological channel using the above method, the vertical direction of Bd*, Bf*, and U can be obtained. D D U A new data sequence of markers, consisting of eight new geological markers: Vd, Vf, Psm, and Rsn, which are re-characterized by the amplitude values ​​of the original signal feature points.

[0154] In some embodiments, after the seismic geological data volume is composed of all seismic geological traces, it further includes:

[0155] The selected reservoir sensitivity curves and seismic geological data volumes of the selected standard wells in the study area are uniformly normalized. The well-side seismic geological channels of the standard wells are extracted from the normalized seismic geological data volume, and a matching consistency analysis is performed with the reservoir sensitivity curves of the standard wells to determine the lateral correction amount of the extracted well-side seismic geological channels. Based on the lateral correction amount, the correction of all seismic geological channels in the seismic geological data volume is completed. The corrected seismic geological channels are then denormalized. The final seismic geological data volume is composed of all the denormalized seismic geological channels.

[0156] For the lithology / facies sensitive well curves of the target reservoir—the well-side geological channels—normalization processing, well-seismic consistency matching cross-analysis, and multi-well-control geological curve standardization processing (histogram technology) are first performed. Then, the necessary amplitude of the target stratigraphic seismic geological data body (all channels) is successively stretched or compressed and corrected, and the geological curve attribute values ​​are denormalized. Finally, a new seismic geological data body with geological / sequence-lithology-facies meaning is obtained.

[0157] By using reservoir-sensitive logging curves from standard wells to perform overall stretching or compression correction on the initially generated seismic geological data volume, the new seismic geological channels are truly endowed with sequence-lithology-lithofamination connotations, rather than merely remaining at the mathematical (Hilbert transform) or physical meaning, which is more conducive to subsequent research on the sedimentary characteristics of thin reservoirs based on new attributes.

[0158] This invention uses the "signal overlay technology" to analyze the new signal after overlaying post-stack seismic data. First, through forward modeling of the sequence-geophysical model, the response relationship between several important characteristic points of the time-domain post-stack seismic trace waveform and sequence stratigraphic / cycle characteristic points is constructed. This achieves positional conversion and a 90° phase shift between the two types of characteristic points, meaning that while the point position remains unchanged, the point nature changes from "seismic" to "sequence," thus interpreting the connotation of sequence constraints. Second, regarding the amplitude of the new characteristic point attributes, the "kinetic-elastic potential energy conservation principle: potential energy ←→ kinetic energy conversion" and "seismic waveform dynamics characteristic analysis: Euler calculation approach between the real and imaginary parts of the signal in the complex trace-Hilbert transform" are used to analyze several different waveform structure patterns, inheriting the original values ​​of adjacent peaks or troughs of the original signal. (Positive values ​​are taken) Different calculation formulas are used to re-characterize the attribute values ​​of eight different geological feature points of the new waveform. Then, cosine function interpolation is used to reconstruct the complete new geological trace waveform for each discrete geological feature point. A seismic-geological data volume with a phase shift of +90° and polarity reversal of +180° is generated quickly and conveniently. Finally, based on the "well-seismic dimension intuitive matching method", the target reservoir lithology and lithofacies sensitive well curves and well-side geological curves are first normalized, well-seismic consistency matching interactive analysis is performed, and multi-well geological curves are standardized. Then, the necessary amplitude scaling correction of each trace curve and the geological curve attributes are denormalized. Finally, a new seismic-geological data volume with geological / sequence-lithology-lithofacies meaning is obtained.

[0159] Figure 9 The image shows a comparison between a traditional 90° phase shift data volume slice (top) and a seismic geological data volume slice obtained in this embodiment (bottom). The seismic geological data volume slice obtained in this embodiment demonstrates good profile resolution and continuity of the same phase axis, increased information content, and improved signal-to-noise ratio. At the same time, in the comparison of instantaneous amplitude attribute volume slices, the new method shows higher local visual resolution and relatively clear and reasonable geological body boundary details.

[0160] This embodiment can be applied to the transformation of all post-stack 3D seismic data volumes, which can quickly and directly obtain seismic geological data volumes similar to those of traditional 90° phase shift + 180° polarity reversal, and have geological sequence meaning.

[0161] Example 2

[0162] This invention provides a specific application of a method for generating seismic geological data volumes. The Bohai Bay Basin-Jizhong Depression-Raoyang Depression-Gaoyang Low Uplift is located on the west side of the Lixian Slope Zone and is adjacent to the Xiliu Oilfield on the east side. It mainly develops two main oil-bearing strata: the first sub-member of the Tertiary delta front subfacies, the Sha-1 sub-member, and the second sub-member of the Sha-2 sub-member, the upper sub-member. The prediction of thin reservoir sedimentary microfacies is an important task in this area.

[0163] Figure 10 This involves the recalibration and tracking of stratigraphic profiles from conventional contiguous post-stack data and 90° phase-shifted topology data (seismic geological data obtained through the method described in this embodiment). The latter demonstrates significantly superior well-seismic calibration and resolution for the target layer and thin sand layers, with a profile resolution improvement of more than 100%. The old profile could only identify thin interbedded groups or composite thick-layer units, while the new phase-shifted data profile can detect thin-layer units. The overall consistency between well logging reservoirs and the original seismic waveforms and geological curve responses (single-wave detection) is improved by more than 40% (50% → 90%). Therefore, from the perspective of improving seismic signal resolution, topology processing and 90° phase-shift transformation of the original data are essential technical means, highlighting the advantages of the new method.

[0164] Because the impedance properties of this area are more sensitive to lithology and lithofacies than conventional seismic properties, two types of data volume impedance inversion profiles were obtained based on the high-9 continuous banded frequency-spreading data volume and the new method of frequency-spreading 90° phase shift (…). Figure 11 This demonstrates the differences between the two methods in terms of resolution, sensitivity, and accuracy and rationality in describing the continuity of sand bodies between wells (Es1-Es2 thin sand bodies). The 90° phase-shift data shows a clearer impedance inversion profile and better lateral impedance continuity, exhibiting a significant resolution advantage. This is illustrated through comparative analysis of the two inversion body slices (…). Figure 12 , Figure 13 The 90° phase-shift impedance volume spatial imaging effect is clearer and more reasonable, and can better describe the sedimentary microfacies planar distribution characteristics of the two main oil-bearing sand layers ES1x-1 and ES1x-2 in the lower segment of the Shahejie Formation: ES1x-1 and ES1x-2—developed with lobed bodies resembling the front edge of a river delta, with a relatively obvious main channel extending in a north-south direction. The entire area is widely distributed with underwater network-branched medium to small channels, network-branched channels, mouth bars, distal sand bars, and small littoral to shallow lacustrine shoal-bar sand bodies, which has been well verified by inversion pumping wells. Figure 14 The geological conditions of the reservoirs (G23, XL24X, XL16X, XL3, G109, G9) are strong. However, the inversion results of the unshifted topology data do not match or partially match the well logging sedimentary facies interpretation conclusions of the four verification wells (XL16X, XL3, G109, G9) (ES1x-1, ES1x-2). The overall well verification consistency rates of the two with the well logging sedimentary facies are 81% and 92%, respectively. The geological results map of the reservoir sedimentary characteristics characterized by the new method and new data in this area has been highly recognized by the client. Figure 15 ).

[0165] In addition, the new method was also applied to the prediction of thin gas reservoirs in the Carboniferous-Permian strata of the unconventional gas reservoir area in the Ordos Basin. A comparison was made between the effects of the traditional 90° facies shift and the new method on two data volume profiles and reservoir lithology / lithofacies sensitive attributes (P1t Taiyuan Formation, lower part: analysis window length—6ms). Figure 16). ) Comparison of well profiles between new and old phase shift data: The stratigraphic calibration accuracy and time resolution are basically the same (both are based on frequency extension data and have drift), but the local wave group characteristics are somewhat different, and the reflection polarities are opposite.

[0166] 2) Comparison of planar predictions based on the relative sensitivity of thin sand layer sedimentary facies: The overall agreement between the traditional 90° and new 90° facies shift data and the well (well logging sedimentary facies) is 75% and 90%, respectively. Specifically, for traditional 90° facies shift attributes: the agreement rate for wells SM-19 and SM-04 is very poor (<40%); for SM-15 it is average (60-70%); but for wells SM-20, SM-01, and SM-16, the predictions from the two methods are basically consistent (±90%). Multi-well validation using P1t reservoir development thickness maps shows that the new method has higher prediction accuracy and effectiveness. Figure 17 ).

[0167] By shifting the phase of seismic data by 90° and reversing its polarity by 180°, the planar geological information is enriched, enabling better alignment of reservoir targets with the actual seismic reflection target layers and locations. At the same time, seismic or inversion attributes can be directly assigned geological concepts, and the time analysis window can be selected reasonably, effectively, and accurately to achieve more accurate prediction results for the identification of sedimentary (micro) facies and planar distribution of thin reservoirs. This allows for a more reasonable, effective, and refined characterization of the main target layers and the spatial distribution of favorable reservoirs.

[0168] The geological information in the above figures is shown in the corresponding attached figures, and will not be repeated here.

[0169] Based on the inventive concept of this invention, embodiments of this invention also provide a seismic geological data volume generation device, the structure of which is as follows: Figure 18 As shown, it includes:

[0170] The seismic waveform feature point identification module 181 is used to extract seismic traces of a target segment from the seismic data volume, identify seismic waveform feature points of a set type in the seismic traces, and delete sample points other than seismic waveform feature points in the seismic traces.

[0171] The geological waveform marker conversion module 182 is used to mark the seismic waveform feature points to the corresponding positions on the geological time axis according to the reflection time, and convert the seismic waveform feature points into geological waveform marker points.

[0172] The geological tunnel marker sequence acquisition module 183 is used to complete the lateral offset of the geological waveform markers according to the predetermined type correspondence and amplitude conversion relationship between seismic waveform feature points and geological waveform markers, and obtain the geological tunnel marker sequence.

[0173] The seismic geological data body construction module 184 is used to interpolate between two adjacent markers in the geological trace marker sequence to obtain seismic geological traces, and all seismic geological traces constitute the seismic geological data body.

[0174] Regarding the apparatus in the above embodiments, the specific manner in which each module performs its operation has been described in detail in the embodiments related to the method, and will not be elaborated upon here.

[0175] Based on the inventive concept of the present invention, embodiments of the present invention also provide a computer program product with seismic geological data volume generation function, including a computer program / instruction, wherein the computer program / instruction, when executed by a processor, implements the above-mentioned seismic geological data volume generation method.

[0176] Based on the inventive concept of the present invention, an embodiment of the present invention also provides a server, including: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the program to implement the above-described method for generating seismic geological data.

[0177] Unless otherwise specifically stated, terms such as processing, calculation, operation, determination, display, etc., may refer to the actions and / or processes of one or more processing or computing systems or similar devices that represent the manipulation and conversion of data representing physical (e.g., electronic) quantities within the registers or memory of the processing system into other data similarly representing physical quantities within the memory, registers, or other such information storage, transmission, or display devices of the processing system. Information and signals can be represented using any of a variety of different techniques and methods. For example, data, instructions, commands, information, signals, bits, symbols, and chips mentioned throughout the above description can be represented by voltage, current, electromagnetic waves, magnetic fields or particles, light fields or particles, or any combination thereof.

[0178] It should be understood that the specific order or hierarchy of steps in the disclosed process is an example of an exemplary method. Based on the design-programmed implementation, it should be understood that the specific order or hierarchy of steps in the process can be rearranged without departing from the scope of this disclosure. The appended method claims provide elements of various steps in an exemplary order and are not intended to limit one to the specific order or hierarchy described.

[0179] In the detailed description above, various features are combined together in a single embodiment to simplify this disclosure. This approach to disclosure should not be construed as reflecting an intention that embodiments of the claimed subject matter require more features than are explicitly stated in each claim. Rather, as reflected in the appended claims, the invention is presented with fewer features than all of the features in a single disclosed embodiment. Therefore, the appended claims are hereby explicitly incorporated into the detailed description, with each claim representing a separate preferred embodiment of the invention.

[0180] Those skilled in the art will also understand that the various illustrative logic blocks, modules, circuits, and algorithm steps described in conjunction with the embodiments herein can be implemented as electronic hardware, computer software, or a combination thereof. To clearly illustrate the interchangeability between hardware and software, the various illustrative components, blocks, modules, circuits, and steps described above are generally described in terms of their functionality. Whether such functionality is implemented as hardware or software depends on the specific application and the design constraints imposed on the overall system. Those skilled in the art can implement the described functionality in alternative ways for each specific application; however, such implementation decisions should not be construed as departing from the scope of this disclosure.

[0181] The steps of the methods or algorithms described in conjunction with the embodiments herein can be directly embodied in hardware, software modules executed by a processor, or a combination thereof. The software modules can reside in RAM memory, flash memory, ROM memory, EPROM memory, EEPROM memory, registers, hard disks, removable disks, CD-ROMs, or any other form of storage medium well known in the art. An exemplary storage medium is connected to the processor, enabling the processor to read information from and write information to the storage medium. Of course, the storage medium can also be a component of the processor. The processor and storage medium can reside in an ASIC. The ASIC can reside in a user terminal. Alternatively, the processor and storage medium can exist as discrete components in the user terminal.

[0182] For software implementation, the techniques described in this application can be implemented using modules (e.g., procedures, calculation formulas, interpolation functions, etc.) that perform the functions described in this application. This software code can be stored in memory units and executed by a processor. The memory units can be implemented within the processor or externally; in the latter case, they are communicatively coupled to the processor via various means, as is well known in the art.

[0183] The foregoing description includes examples of one or more embodiments. It is certainly impossible to describe all possible combinations of methods in order to describe the above embodiments, but those skilled in the art will recognize that further combinations and arrangements of the various embodiments are possible. Therefore, the embodiments described herein are intended to cover all such changes, modifications, and variations that fall within the scope of the appended claims. Furthermore, the term “comprising” as used in the specification or claims is interpreted in a manner similar to the term “including,” as interpreted as a conjunction in the claims. Additionally, the use of any term “or” in the specification of the claims is intended to mean “non-exclusive or.”

Claims

1. A method for generating seismic geological data volumes, characterized in that, include: Seismic traces of the target segment are extracted from the seismic data volume, seismic waveform feature points of a set type are identified in the seismic traces, and sample points other than the seismic waveform feature points in the seismic traces are deleted. Based on the reflection time, the seismic waveform feature points are marked to the corresponding positions on the geological time axis to obtain the geological waveform marker points; According to the predetermined type correspondence between seismic waveform feature points and geological waveform marker points, the type of geological waveform marker points is determined based on the type of seismic waveform feature points, and the lateral offset direction is determined based on the type of geological waveform marker points. According to the predetermined amplitude conversion relationship between seismic waveform feature points and geological waveform marker points, the absolute value of the amplitude of the geological waveform marker points is determined; the lateral offset of the geological waveform marker points is completed according to the determined lateral offset direction and absolute value of amplitude to obtain the geological trace marker point sequence; Interpolation is performed between two adjacent markers in the geological channel marker sequence to obtain seismic geological channels, and all seismic geological channels constitute the seismic geological data volume.

2. The method as described in claim 1, characterized in that, The type correspondence between the seismic waveform feature points and the geological waveform marker points is predetermined in the following manner: Based on the seismic forward modeling results of a one-dimensional cyclic model, a type correspondence between seismic waveform feature points and geological waveform marker points is constructed.

3. The method as described in claim 1, characterized in that, The amplitude conversion relationship between seismic waveform feature points and geological waveform marker points is predetermined using the following method: By utilizing the principles of conservation and conversion of kinetic and elastic potential energy of particle vibration during seismic wave propagation, combined with seismic wave dynamics characteristic analysis and seismic forward modeling results of a one-dimensional cyclic model, the amplitude conversion relationship between characteristic points of seismic waveforms and marker points of geological waveforms is determined.

4. The method as described in claim 1, characterized in that, The identification of seismic waveform feature points of a predetermined type in the seismic trace specifically includes identifying at least one of the following types of seismic waveform feature points in the seismic trace: Single-wave peak, complex wave peak with the shortest reflection time, complex wave peak with a non-short reflection time, single-wave trough, complex wave trough with the shortest reflection time, complex wave trough with a non-short reflection time, first amplitude zeroing point, second amplitude zeroing point, maximum negative amplitude of complex wave, minimum positive amplitude of complex wave.

5. The method as described in claim 1, characterized in that, The type correspondence between the seismic waveform feature points and the geological waveform marker points specifically includes at least one of the following: The single-wave peak of the seismic waveform characteristic point corresponds to the first amplitude zero-return point of the geological waveform marker point; The complex wave peak with the shortest reflection time among the complex wave peaks of the seismic waveform characteristic points corresponds to the first amplitude zero-return point of the geological waveform marker point; The complex wave peaks with non-minimum reflection time among the complex wave peaks of the seismic waveform characteristic points correspond to the points with maximum negative complex wave amplitudes of the geological waveform marker points. The single-wave trough T of the seismic waveform characteristic point corresponds to the second amplitude zero-return point of the geological waveform marker point; The complex wave valley with the shortest reflection time in the complex wave valley of the seismic waveform characteristic point corresponds to the second amplitude zero point of the geological waveform marker point; The complex wave valleys with non-minimum reflection time in the characteristic points of seismic waveforms correspond to the minimum points of complex wave positive amplitude in geological waveform markers. The second amplitude zero-point of the seismic waveform characteristic point corresponds to the complex wave peak with the longest reflection time among the single wave peak or complex wave peak of the geological waveform marker point; The first amplitude zero-return point of the seismic waveform characteristic point corresponds to the complex wave valley with the largest relative reflection time in the single wave valley or complex wave valley of the geological waveform marker point; The maximum negative amplitude of the complex wave at the characteristic point of the seismic waveform corresponds to the complex wave peak at the geological waveform marker point where the relative reflection time is not the largest. The minimum positive amplitude of the complex wave at the characteristic point of the seismic waveform corresponds to the complex wave valley at the geological waveform marker point where the relative reflection time is not the maximum.

6. The method as described in claim 5, characterized in that, The determination of the lateral offset direction based on the type of geological waveform marker points specifically includes: If the geological waveform marker point is of type 1 amplitude zero return point or 2 amplitude zero return point, the geological waveform marker point will not shift; If the geological waveform marker is a single wave peak, a complex wave peak with the longest reflection time, a complex wave peak with a non-maximum relative reflection time, or a complex wave peak with a minimum positive amplitude, the offset direction of the geological waveform marker is to the right. If the geological waveform marker is a single-wave valley or a complex wave valley with the largest relative reflection time, a complex wave valley with a non-largest relative reflection time, or a complex wave with a maximum negative amplitude, the offset direction of the geological waveform marker is to the left.

7. The method as described in claim 6, characterized in that, If the geological waveform marker is a single-wave geological waveform marker, determining the absolute value of the amplitude of the geological waveform marker according to the predetermined amplitude conversion relationship between seismic waveform feature points and geological waveform markers specifically includes performing at least one of the following: If the geological waveform marker point is of the type of single wave peak, half of the sum of the absolute amplitude value of the next feature point of the seismic waveform feature point corresponding to the marker point and the absolute amplitude value of the previous feature point shall be determined as the absolute amplitude value of the marker point. If the geological waveform marker is a single-wave valley, the absolute amplitude of the marker is determined by half the sum of the absolute amplitude of the next feature point of the seismic waveform feature point and the absolute amplitude of the previous feature point.

8. The method as described in claim 6, characterized in that, If the geological waveform marker point is a bimodal or bivalve half-cycle waveform marker point, the step of determining the absolute value of the amplitude of the geological waveform marker point according to the predetermined amplitude conversion relationship between seismic waveform characteristic points and geological waveform marker points specifically includes: If the geological waveform marker point is of the type of complex wave peak with the longest reflection time in a double-peak half-cycle waveform, a complex wave peak with a non-longest reflection time in a double-peak half-cycle waveform, a complex wave trough with the longest reflection time in a double-valley half-cycle waveform, or a complex wave trough with a non-longest relative reflection time in a double-valley half-cycle waveform, half of the sum of the absolute amplitude of the next feature point of the seismic waveform feature point corresponding to the marker point and the absolute amplitude of the previous feature point is determined as the absolute amplitude of the marker point. If the geological waveform marker point is a negative amplitude maximum in a double-valley half-cycle waveform or a positive amplitude minimum in a double-peak half-cycle waveform, the absolute amplitude value of the marker point is determined by one-quarter of the sum of the absolute amplitude value of the next marker point and the absolute amplitude value of the previous marker point.

9. The method as described in claim 6, characterized in that, If the geological waveform marker point is a three-peak or three-valley half-cycle waveform marker point, the step of determining the absolute value of the amplitude of the geological waveform marker point according to the predetermined amplitude correspondence between seismic waveform characteristic points and geological waveform marker points specifically includes: If the type of the geological waveform marker point is the complex wave peak with the longest reflection time in the three-peak half-cycle waveform or the complex wave trough with the longest reflection time in the three-valley half-cycle waveform, or the complex wave peak with the longest reflection time in the three-peak half-cycle waveform or the complex wave trough with the longest reflection time in the three-valley half-cycle waveform, then half of the sum of the absolute amplitude value of the next feature point of the seismic waveform feature point corresponding to the marker point and the absolute amplitude value of the previous feature point shall be determined as the absolute amplitude value of the marker point. If the type of geological waveform marker point is the maximum negative amplitude of the complex wave of the three-valley half-cycle waveform or the minimum positive amplitude of the complex wave of the three-peak half-cycle waveform, then one-quarter of the sum of the absolute amplitude of the next marker point and the absolute amplitude of the previous marker point is determined as the absolute amplitude of the marker point.

10. The method as described in claim 1, characterized in that, The seismic geological data body, composed of all seismic geological channels, also includes: The selected reservoir sensitivity curves of the selected standard wells in the study area and the seismic geological data volume are uniformly normalized. The well-side seismic geological channels of the standard wells are extracted from the normalized seismic geological data volume and matched with the reservoir sensitivity curves of the standard wells for consistency analysis to determine the lateral correction amount of the extracted well-side seismic geological channels. The correction of all seismic geological channels in the seismic geological data body is completed according to the lateral correction amount. The corrected seismic geological channels are then denormalized. The final seismic geological data body is composed of all the denormalized seismic geological channels.

11. The method according to any one of claims 1 to 10, characterized in that, The seismic data volume is a seismic data volume that has undergone post-stack and frequency extension processing in sequence.

12. The method as described in claim 11, characterized in that, The interpolation between two adjacent markers in the geological tunnel marker point sequence specifically includes: The cosine function interpolation method is used to interpolate between two adjacent markers in the geological tunnel marker sequence according to the post-stack sampling interval.

13. A device for generating seismic geological data volumes, characterized in that, include: The seismic waveform feature point identification module is used to extract seismic traces of a target segment from the seismic data volume, identify seismic waveform feature points of a set type in the seismic traces, and delete sample points other than the seismic waveform feature points in the seismic traces. The geological waveform marker conversion module is used to mark the seismic waveform feature points to the corresponding positions on the geological time axis according to the reflection time, and convert the seismic waveform feature points into geological waveform marker points. The geological trace marker sequence acquisition module is used to determine the type of geological trace marker based on the type of the seismic waveform feature points and the geological waveform marker points according to the predetermined type correspondence between seismic waveform feature points and geological waveform marker points, and to determine the lateral offset direction of the geological waveform marker points according to the type of the geological waveform marker points. According to the predetermined amplitude conversion relationship between seismic waveform feature points and geological waveform marker points, the absolute value of the amplitude of the geological waveform marker points is determined; the lateral offset of the geological waveform marker points is completed according to the determined lateral offset direction and absolute value of amplitude to obtain the geological trace marker point sequence; The seismic geological data volume construction module is used to interpolate between two adjacent markers in the geological channel marker sequence to obtain seismic geological channels, and all seismic geological channels constitute the seismic geological data volume.

14. A computer program product with seismic geological data volume generation function, comprising a computer program / instructions, characterized in that, When the computer program / instruction is executed by the processor, it implements the method for generating seismic geological data volumes according to any one of claims 1 to 12.

15. A server, characterized in that, include: A memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor, when executing the program, implements the method for generating seismic geological data volumes according to any one of claims 1 to 12.

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