Seismic horizon interpretation method, device, equipment, medium and program product

Abstract

This invention discloses a seismic stratigraphic interpretation method, apparatus, equipment, medium, and program product. It includes: determining the well calibration type of each well based on well data from all wells within the work area; dividing the work area into a transition zone and two calibration zones based on the well calibration types of each well; wherein the calibration type of each calibration zone is the well calibration type of the wells within that zone; performing stratigraphic tracking on the transition zone and the corresponding calibration zones based on the calibration types of each calibration zone to determine the initial stratigraphic interpretation results for the transition zone and the corresponding calibration zone stratigraphic interpretation results for each calibration zone; performing stratigraphic variation rotation on the initial transition zone stratigraphic interpretation results based on the calibration types of each calibration zone and the well data from each well to determine the stratigraphic interpretation results for the transition zone; and concatenating the stratigraphic interpretation results of each calibration zone with the stratigraphic interpretation results of the transition zone to determine the seismic stratigraphic interpretation results for the entire work area. This improves the accuracy and geological detail preservation of the overall seismic stratigraphic interpretation for the work area.

Description

Technical Field

[0001] This invention relates to the field of geophysical exploration technology, and in particular to a seismic horizon interpretation method, apparatus, equipment, medium, and program product. Background Technology

[0002] Seismic stratigraphic interpretation is a crucial foundational task in geophysical research, and the precision of stratigraphic interpretation is essential for structural mapping and reservoir prediction in oil and gas exploration. Traditional automatic stratigraphic tracking methods only support building interpretation grids using individual calibration features (such as peaks, troughs, or zero phase values) as seed points, and then automatically tracking them step by step until interpretation is complete. As exploration precision increases and the work area expands, the drawbacks of individual calibration features, such as structural errors and formation thickness errors, become increasingly apparent.

[0003] In actual production, the calibration position of a stratigraphic level in the synthetic seismic logging record can vary across adjacent regions due to differences in geological structure, reservoir development, and other factors. For example, some regions might be calibrated at the wave crest, others at the wave trough, transitional regions near the phase zero, and even more complex calibrations might occur at the half-amplitude position of the wave crest. These variations in calibration positions across different regions make it difficult to accurately transition between stratigraphic levels in adjacent regions with different calibration positions, and it also makes it difficult to preserve the detailed characteristics of stratigraphic undulations in the transitional regions between different calibration positions.

[0004] Currently, the transition areas between different calibration locations are often interpreted by manual picking or stratigraphic interpolation. However, manual picking has large errors and is difficult to retain high-precision details, while stratigraphic interpolation has a small application range and cannot change the stratigraphic state according to geological undulations, which will lead to the loss of a large number of geological details and make it difficult to meet the needs of oilfield exploration for high-precision interpretation results. Summary of the Invention

[0005] This invention provides a seismic stratigraphic interpretation method, apparatus, equipment, medium, and program product, which improves the accuracy of seismic stratigraphic interpretation in transitional areas within the work area that do not match individual calibration features. It accurately connects areas corresponding to complex calibration situations during the seismic stratigraphic interpretation process with areas calibrated using individual calibration features, and preserves the detailed features of stratigraphic undulations under complex calibration situations. This improves the accuracy of seismic stratigraphic interpretation for the entire work area and the degree of geological detail preservation, meeting the needs of oilfield exploration for high-precision interpretation results.

[0006] In a first aspect, embodiments of the present invention provide a seismic horizon interpretation method, comprising:

[0007] Based on the well data of all wells in the work area, the well calibration type of each well is determined, and the work area is divided into a transition zone and two calibration zones according to the well calibration type of each well; wherein, the zone calibration type of each calibration zone is the well calibration type of the wells in the calibration zone;

[0008] Based on the calibration type of each calibration area, the transition area and the corresponding calibration area are subjected to stratigraphic tracing to determine the initial stratigraphic interpretation results of the transition area and the stratigraphic interpretation results of each calibration area.

[0009] Based on the calibration type of each calibration area and the well data of each well, the initial transition zone stratigraphic interpretation results are rotated to determine the transition zone stratigraphic interpretation results;

[0010] The stratigraphic interpretation results of each calibration zone are combined with the stratigraphic interpretation results of the transition zone to determine the seismic stratigraphic interpretation results of the work area.

[0011] Secondly, embodiments of the present invention also provide a seismic horizon interpretation apparatus, comprising:

[0012] The calibration zone determination module is used to determine the well calibration type of each well based on the well data of all wells in the work area, and to divide the work area into a transition zone and two calibration zones according to the well calibration type of each well; wherein, the zone calibration type of each calibration zone is the well calibration type of the wells in the calibration zone;

[0013] The calibration result determination module is used to perform stratigraphic tracing on the transition zone and the corresponding calibration zone according to the zone calibration type of each calibration zone, and to determine the initial stratigraphic interpretation result of the transition zone and the stratigraphic interpretation result of each calibration zone.

[0014] The transition result determination module is used to perform stratigraphic change rotation on the initial transition zone stratigraphic interpretation results based on the zone calibration type of each calibration zone and the well data of each well, and to determine the transition zone stratigraphic interpretation results.

[0015] The seismic horizon interpretation module is used to combine the horizon interpretation results of each calibration zone with the horizon interpretation results of the transition zone to determine the seismic horizon interpretation results of the work area.

[0016] Thirdly, embodiments of the present invention also provide a seismic horizon interpretation device, the seismic horizon interpretation device comprising:

[0017] At least one processor; and a memory communicatively connected to the at least one processor;

[0018] The memory stores a programmable program that can be executed by at least one processor, which enables the at least one processor to implement the seismic horizon interpretation method of any embodiment of the present invention.

[0019] Fourthly, embodiments of the present invention also provide a storage medium containing computer-executable instructions, which, when executed by a computer processor, are used to perform the seismic horizon interpretation method of any embodiment of the present invention.

[0020] Fifthly, embodiments of the present invention also provide a computer program product, including a computer program, which, when executed by a processor, is used to perform the seismic horizon interpretation method of any embodiment of the present invention.

[0021] This invention provides a seismic horizon interpretation method, apparatus, equipment, medium, and program product. It determines the well calibration type of each well based on well data from all wells within the work area, and divides the work area into a transition zone and two calibration zones based on the well calibration types. The calibration type of each calibration zone is the well calibration type of the wells within that zone. Horizontal tracking is performed on the transition zone and the corresponding calibration zones based on their respective calibration types to determine the initial transition zone horizon interpretation results and the corresponding calibration zone horizon interpretation results. Horizontal variation rotation is applied to the initial transition zone horizon interpretation results based on the calibration types of each calibration zone and the well data from each well to determine the transition zone horizon interpretation results. Finally, the horizon interpretation results of each calibration zone are combined with the transition zone horizon interpretation results to determine the seismic horizon interpretation results for the work area. By adopting the above technical solution, the well calibration type required for calibrating the stratigraphy in different wells will be determined first based on the well data of the completed stratigraphy determination in the work area. Then, the work area will be divided into regions according to the different well calibration types to obtain calibration areas that can be automatically tracked and interpreted by seismic stratigraphy through clear calibration standards, as well as transition areas located between different calibration areas that cannot be automatically tracked and interpreted by seismic stratigraphy through clear calibration standards. For the calibration area, an automatic seismic stratigraphic tracking method corresponding to the calibration type of the calibration area is used to process it to obtain the stratigraphic interpretation results for the calibration area. For the transition area, the initial stratigraphic interpretation results obtained from the preliminary processing in the transition area are rotated based on the calibration type of the surrounding calibration areas and well data throughout the entire work area. This allows the rotated stratigraphic interpretation results of the transition area to smoothly transition and connect with the stratigraphic interpretation results of the calibration area at the boundary of the calibration area. Within the transition area, the interpreted stratigraphic results are gradually transitioned from the stratigraphic interpretation results of one calibration area to the stratigraphic interpretation results of the other calibration area. During this transition process, as much detail of stratigraphic undulations in the transition area as possible is preserved. After completing the stratigraphic interpretation of the transition area, the stratigraphic interpretation results of the transition area are stitched together with the stratigraphic interpretation results of each calibration area to obtain the seismic stratigraphic interpretation results of the entire work area. This improves the accuracy of the overall seismic stratigraphic interpretation of the work area and the degree of geological detail preservation, meeting the needs of oilfield exploration for high-precision interpretation results.

[0022] It should be understood that the description in this section is not intended to identify key or essential features of the embodiments of the present invention, nor is it intended to limit the scope of the invention. Other features of the invention will become readily apparent from the following description. Attached Figure Description

[0023] To more clearly illustrate the technical solutions in the embodiments of the present invention, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0024] Figure 1 This is a flowchart illustrating a seismic horizon interpretation method provided in Embodiment 1 of the present invention;

[0025] Figure 2 This is a flowchart illustrating a seismic horizon interpretation method provided in Embodiment 2 of the present invention;

[0026] Figure 3 This is an example diagram of a synthetic seismic record for calibrating the bottom boundary of the Qixia Formation, provided in Embodiment 2 of the present invention.

[0027] Figure 4 This is an example diagram of a work area zoning based on the pinch-out line of the underlying strata of the Qixia Formation, provided in Embodiment 2 of the present invention;

[0028] Figure 5 This is an example cross-sectional view of the calibration region for a zero-phase calibration type, provided in Embodiment 2 of the present invention.

[0029] Figure 6 This is an example cross-sectional view of a calibration area for a trough calibration type provided in Embodiment 2 of the present invention;

[0030] Figure 7 This is an example cross-sectional view of the initial transition zone stratigraphic interpretation provided in Embodiment 2 of the present invention;

[0031] Figure 8 This is an example diagram illustrating the transformation process of a rotation trend surface provided in Embodiment 2 of the present invention;

[0032] Figure 9 This is a schematic diagram of the structure of a seismic horizon interpretation device provided in Embodiment 3 of the present invention;

[0033] Figure 10 This is a structural schematic diagram of a seismic horizon interpretation device provided in Embodiment 4 of the present invention. Detailed Implementation

[0034] To enable those skilled in the art to better understand the present invention, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of the present invention.

[0035] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of the invention described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover a non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0036] Example 1

[0037] Figure 1 This is a flowchart illustrating a seismic horizon interpretation method provided in Embodiment 1 of the present invention. This embodiment is applicable to situations requiring automatic seismic horizon tracking and interpretation within work areas affected by different geological structures, reservoir development, and other factors. The method can be executed by a seismic horizon interpretation device, which can be implemented using software and / or hardware and can be configured within a seismic horizon interpretation equipment. Optionally, the seismic horizon interpretation equipment can be an electronic device, such as a laptop, desktop computer, or smart tablet, etc. This embodiment of the present invention does not impose any limitations on this.

[0038] like Figure 1 As shown in the figure, the seismic horizon interpretation method provided by this embodiment of the invention specifically includes the following steps:

[0039] S101. Determine the well calibration type of each well based on the well data of all wells in the work area, and divide the work area into a transition zone and two calibration zones according to the well calibration type of each well.

[0040] Among them, the zone calibration type of each calibration zone is the well calibration type of the wells within the calibration zone.

[0041] In this embodiment, the work area can be specifically understood as the area where oil and gas exploration is required. A well can be specifically understood as a data well within the work area used to obtain geological, geophysical, and geochemical subsurface information, primarily for providing direct subsurface samples and data for geological research and resource assessment. Well data can be specifically understood as logging data and other data obtained from logging operations performed on data wells during oilfield development, containing detailed information such as subsurface rock properties and oil-bearing characteristics. It can be understood that well data can determine the specific subsurface distribution of the required interpretation strata corresponding to the well within the work area. Well calibration type can be specifically understood as the representation of the calibration location in the seismic record when the required seismic strata are accurately calibrated in the subsurface conditions corresponding to the well. For example, well calibration types may include positive wave trough calibration, - / + zero phase calibration, and positive wave peak calibration, etc., and this embodiment of the invention does not limit this. Calibration area can be specifically understood as the area within the work area where wells that can be calibrated by clearly defined and fixed locations in the seismic record are located. The transition zone can be specifically understood as the area in the work area where wells cannot be clearly and fixedly calibrated in the seismic record. For example, the calibration zone can be specifically understood as the area where wells are located where the required seismic horizons can be calibrated using crests, troughs, or zero phase; the transition zone can be specifically understood as the area where wells are located where the required seismic horizons are located between crests and zero phase or between troughs and zero phase, and where seismic horizons cannot be simply calibrated using crests, troughs, or zero phase.

[0042] Specifically, when seismic horizon interpretation is required within the work area, well data collected from each well used for subsurface information acquisition can be obtained first. Based on the well data, the specific subsurface distribution of the required interpretation horizons at corresponding points of different wells can be determined. This allows for the determination of the representation of the required interpretation horizon in the seismic records corresponding to different wells, and the determination of different well calibration types for each well based on these different representations. After the well calibration types of all wells are determined, wells belonging to the same calibration type are grouped into the same area. This allows the work area to be divided into two calibration zones where seismic horizons can be clearly and consistently located in the seismic records, and a transition zone between the two calibration zones where seismic horizons cannot be clearly and consistently located in the seismic records.

[0043] It is understandable that since all wells within the same calibration area have the same well calibration type, the well calibration type can be determined as the zone calibration type used for calibrating seismic horizons within that calibration area.

[0044] S102. Based on the calibration type of each calibration area, perform stratigraphic tracing on the transition area and the corresponding calibration area to determine the initial stratigraphic interpretation results of the transition area and the stratigraphic interpretation results of each calibration area.

[0045] In this embodiment, the initial transition zone stratigraphic interpretation result can be specifically understood as the result of randomly applying a stratigraphic calibration method to interpret the stratigraphic layers in the transition zone, where seismic layers are calibrated at clear and fixed locations in the seismic record. The calibration zone stratigraphic interpretation result can be specifically understood as the result of applying a stratigraphic calibration method corresponding to the calibration type of the calibration zone to interpret the seismic layers.

[0046] Specifically, since each calibration area has its own corresponding and accurate calibration type, the seismic records within each calibration area can be automatically traced and interpreted using its own corresponding calibration type. The result is then determined as the calibration area's stratigraphic interpretation result. However, since the transition zone cannot be automatically traced and interpreted based on a single calibration type, a preliminary seismic stratigraphic interpretation is still required for subsequent processing. Here, it can be assumed that the transition zone has the same stratigraphic calibration characteristics as any calibration area. That is, a calibration type can be randomly selected from the calibration types of each calibration area as the calibration type for automatic stratigraphic tracing and interpretation of the transition zone. The seismic records in the transition zone are then automatically traced and interpreted using this calibration type, and the result is determined as the initial transition zone stratigraphic interpretation result.

[0047] S103. Based on the calibration type of each calibration area and the well data of each well, perform stratigraphic variation rotation on the initial transition zone stratigraphic interpretation results to determine the transition zone stratigraphic interpretation results.

[0048] Specifically, since the transition zone is the area between each calibration zone, the calibration position corresponding to the stratigraphic calibration of each seismic record in the transition zone should be located in the middle of the corresponding calibration positions in the seismic records of the two calibration zones. Therefore, based on the calibration type of each calibration zone, the range of smoothing transformation required for the stratigraphic calibration position in the transition zone can be clearly defined. Furthermore, based on the well data of each well, the time difference corresponding to the transformation of the initial stratigraphic interpretation results in the transition zone can be further clarified. Based on the above smoothing transformation range and time difference, the initial stratigraphic interpretation results in the transition zone are rotated and transformed so that the stratigraphic calibration results at the two positions connecting with the calibration zones are consistent with the stratigraphic interpretation results of the corresponding calibration zones. In the transition zone, the stratigraphic undulation details contained in the initial stratigraphic interpretation results can be preserved as much as possible, and the final stratigraphic interpretation results of the transition zone are obtained.

[0049] S104. Combine the stratigraphic interpretation results of each calibration zone with the stratigraphic interpretation results of the transition zone to determine the seismic stratigraphic interpretation results of the work area.

[0050] Specifically, since each calibration zone and transition zone has a clear and accurate boundary, after clarifying the stratigraphic interpretation results of each calibration zone and the transition zone, the stratigraphic interpretation results of each calibration zone and the transition zone can be spliced ​​together based on the specific coordinates of the boundary within the work area. The spliced ​​result is then determined as the seismic stratigraphic interpretation result of the work area.

[0051] The technical solution of this embodiment determines the well calibration type of each well based on the well data of all wells in the work area, and divides the work area into a transition zone and two calibration zones according to the well calibration type of each well. The calibration type of each calibration zone is the well calibration type of the wells within that zone. Based on the calibration type of each calibration zone, stratigraphic tracking is performed on the transition zone and the corresponding calibration zone to determine the initial stratigraphic interpretation results of the transition zone and the corresponding stratigraphic interpretation results of each calibration zone. Based on the calibration type of each calibration zone and the well data of each well, the initial transition zone stratigraphic interpretation results are rotated to determine the stratigraphic interpretation results of the transition zone. The stratigraphic interpretation results of each calibration zone are then combined with the stratigraphic interpretation results of the transition zone to determine the seismic stratigraphic interpretation results of the work area. By adopting the above technical solution, the well calibration type required for calibrating the stratigraphy in different wells will be determined first based on the well data of the completed stratigraphy determination in the work area. Then, the work area will be divided into regions according to the different well calibration types to obtain calibration areas that can be automatically tracked and interpreted by seismic stratigraphy through clear calibration standards, as well as transition areas located between different calibration areas that cannot be automatically tracked and interpreted by seismic stratigraphy through clear calibration standards. For the calibration area, an automatic seismic stratigraphic tracking method corresponding to the calibration type of the calibration area is used to process it to obtain the stratigraphic interpretation results for the calibration area. For the transition area, the initial stratigraphic interpretation results obtained from the preliminary processing in the transition area are rotated based on the calibration type of the surrounding calibration areas and well data throughout the entire work area. This allows the rotated stratigraphic interpretation results of the transition area to smoothly transition and connect with the stratigraphic interpretation results of the calibration area at the boundary of the calibration area. Within the transition area, the interpreted stratigraphic results are gradually transitioned from the stratigraphic interpretation results of one calibration area to the stratigraphic interpretation results of the other calibration area. During this transition process, as much detail of stratigraphic undulations in the transition area as possible is preserved. After completing the stratigraphic interpretation of the transition area, the stratigraphic interpretation results of the transition area are stitched together with the stratigraphic interpretation results of each calibration area to obtain the seismic stratigraphic interpretation results of the entire work area. This improves the accuracy of the overall seismic stratigraphic interpretation of the work area and the degree of geological detail preservation, meeting the needs of oilfield exploration for high-precision interpretation results.

[0052] Example 2

[0053] Figure 2 This is a flowchart illustrating a seismic horizon interpretation method provided in Embodiment 2 of the present invention. Based on the aforementioned optional technical solutions, this embodiment further optimizes the method by constructing a synthetic seismic record for each well using well data acquired within the work area. The synthetic seismic record is then calibrated using accurate layering information contained in the well data, specifically for the required seismic horizon interpretation, to accurately determine the well calibration type for each well. Furthermore, based on different well calibration types, each well is divided into regions. Between wells with transitional calibration types and those without, the geological boundary lines are analyzed to determine the transition zone boundary between the transition zone and the calibration zone. Finally, based on the transition zone boundary lines and the work area boundary lines, the entire work area is precisely divided into a transition zone and two calibration zones. After completing the preliminary interpretation of the transition zone and the automatic interpretation of the calibration zone based on the calibration type of each calibration zone, the difference between the initial transition zone stratigraphic interpretation result and the transition zone stratigraphic change trend surface obtained by smoothing the initial transition zone stratigraphic interpretation result is used to obtain the transition zone difference surface that preserves the stratigraphic undulation details in the transition zone. Then, based on the well data of each well and the calibration type of each calibration zone, the time difference parameter required for stratigraphic change rotation is determined. Based on the time difference parameter, the transition zone stratigraphic change trend surface is rotated to obtain the rotation target trend surface that can make the change trend transition smoothly. Then, the rotation target trend surface is superimposed with the transition zone difference surface that preserves the stratigraphic undulation details as the transition zone stratigraphic interpretation result. This ensures that the transition zone stratigraphic interpretation result can retain sufficient stratigraphic undulation details and enable a smooth transition between adjacent calibration zones for stratigraphic calibration. Furthermore, the accuracy of the boundary delineation of the transition zone improves the splicing accuracy of the stratigraphic interpretation results of each calibration zone with those of the transition zone, thereby enhancing the accuracy of the overall seismic stratigraphic interpretation of the work area and the degree of preservation of geological details, thus meeting the oilfield exploration demand for high-precision interpretation results.

[0054] like Figure 2 As shown in the figure, the seismic horizon interpretation method provided by this embodiment of the invention specifically includes the following steps:

[0055] S201. Obtain well data for all wells within the work area.

[0056] S202. For each well, determine accurate stratification information and synthetic seismic records based on well data, and calibrate the synthetic seismic records using accurate stratification information to determine the well calibration type.

[0057] In this embodiment, the synthetic seismic record can be understood as a seismic trace model generated based on well logging curve data and seismic wavelet convolution contained in the well data. Accurate stratigraphic information can be understood as information determined based on well logging information or geological information in the well data, used to characterize the specific location of the seismic horizon to be interpreted.

[0058] Specifically, for the well data acquired from each well within the work area, a unified wavelet, i.e., a synthetic seismic record with a unified wavelet type and frequency, can be generated for each well based on the data from each well. Simultaneously, accurate stratigraphic information, which can be used to characterize the specific location distribution of the seismic horizons to be interpreted at the well location, can be determined from the well data for each well. For each well, its synthetic seismic record and accurate stratigraphic information are matched. At this point, each synthetic seismic record can be calibrated using the accurate stratigraphic information. Based on the position information of the calibration point on the waveform in the synthetic seismic record, the well calibration type can be determined.

[0059] For example, assuming the calibration point is in a special location in the synthetic seismic record, such as a peak, trough, or - / + zero phase, the calibration type corresponding to the special location can be used as the well calibration type; while for the case where the calibration point is not in a special location in the synthetic seismic record, the well calibration type can be determined as a transitional calibration type. Figure 3 This is an example diagram of a synthetic seismic record for calibrating the bottom boundary of the Qixia Formation, provided in Embodiment 2 of the present invention. Figure 3 As shown, this includes synthetic seismic records constructed from data from three different wells, and the bottom boundary of the Qixia Formation has been calibrated for each synthetic seismic record based on accurate stratigraphic information from each well. Specifically, well GS16 on the left clearly shows the bottom boundary of the Qixia Formation located at a trough in the synthetic seismic record; well MX145 on the right clearly shows the bottom boundary of the Qixia Formation located at the zero-phase position in the synthetic seismic record; and well MX41 in the middle shows the bottom boundary of the Qixia Formation located between the trough and the zero-phase position. In summary, the calibration type for well GS16 can be determined as a trough calibration type, the calibration type for well MX145 as a zero-phase calibration type, and the calibration type for well MX41 as a transitional calibration type.

[0060] S203. The geological boundary between wells with a well calibration type of transitional calibration type and wells with a well calibration type of non-transitional calibration type shall be determined as the boundary line of the transition zone.

[0061] Specifically, by grouping wells belonging to the same calibration type into one area, the work area can be divided into a transition zone and two calibration zones. Changes in the calibration position of stratigraphic layers in the synthetic seismic record must be due to changes in seismic wave transmission conditions. This means that the seismic wave transmission conditions between wells with a transition calibration type and those with a different type must have changed. To accurately characterize the transition zone and calibration zones, a geological boundary line can be found between wells with a transition calibration type and those without, and this geological boundary line can be used as the boundary line between the transition zone and the calibration zones.

[0062] Optional geological boundaries include at least one of the following:

[0063] Lithological variation trend line;

[0064] pinch-out line of overlying strata;

[0065] Pinch-out line of the underlying strata;

[0066] Lines showing variations in stratigraphic thickness;

[0067] Special geological structural lines.

[0068] S204. Based on the boundary line of the work area and the boundary line of the transition area, the work area is divided into a transition area and two calibration areas.

[0069] Among them, the zone calibration type of each calibration zone is the well calibration type of the wells within the calibration zone.

[0070] Specifically, since a transition zone boundary line can be used to distinguish between a transition zone and a calibration zone, the area formed by the boundary line of the work area and a transition zone boundary line can be defined as a calibration zone, and the area formed by the boundary line of the work area and two transition zone boundary lines can be defined as a transition zone.

[0071] For example, Figure 4 This is an example diagram of a work area zoning based on the pinch-out line of the underlying strata of the Qixia Formation, provided in Embodiment 2 of the present invention. The work area is defined as follows: Figure 4 The area corresponding to the medium grid is represented by different symbols for different well calibration types. Figure 4 The diagram shows the determination of the transition zone boundary line between the transition zone and the calibration zone based on the pinch-out line of the underlying strata in the geological boundary line. It can be considered that... Figure 4 The upper middle part is the calibration area for zero-phase calibration, the lower part is the calibration area for trough calibration, and the area in the middle formed by the transition zone boundary line represented by two dashed lines and the boundary lines of the two work areas at the lower left and lower right is the transition zone.

[0072] S205. For each calibration area, perform stratigraphic tracing corresponding to the calibration type of the calibration area to determine the stratigraphic interpretation result of the calibration area.

[0073] Specifically, for each calibration area, since the geological conditions within the calibration area are similar, the same calibration type can be used to automatically track and interpret seismic horizons within the area. For example, if the calibration type is zero-phase calibration, the zero-phase position of each seismic trace in each seismic profile within the calibration area can be calibrated and tracked, and all zero-phase position points can be calibrated and connected to obtain the calibration area horizon interpretation results for that calibration area.

[0074] For example, Figure 5This is an example of a stratigraphic interpretation section of a calibration region for a zero-phase calibration type provided in Embodiment 2 of the present invention, as shown in the figure. Figure 5 As shown, the interpreted profile is the profile shown by the thick black line in the work area on the left side of the figure. H0(x,y) is the result of the layer interpretation obtained after the seismic layers are calibrated and connected in this profile. It can be clearly seen that the seismic layers calibrated in each waveform are all the zero phase points. Figure 6 This is an example of a stratigraphic interpretation section of a calibration area for a trough calibration type provided in Embodiment 2 of the present invention, as shown in the figure. Figure 6 As shown, the cross-section it interprets is the one shown by the thick black line in the work area on the left side of the figure, H. T (x,y) represents the interpretation result of the seismic horizons after calibration and connection in this profile. It can be clearly seen that the seismic horizons in each waveform are all troughs.

[0075] S206. Select one of the calibration types from each calibration area as the initial calibration type for the transition area, and perform stratigraphic tracing on the transition area corresponding to the initial calibration type to determine the stratigraphic interpretation result of the initial transition area.

[0076] Specifically, since the calibration location corresponding to the transition zone differs from the calibration location corresponding to the zonal calibration types of each calibration zone, accurate stratigraphic interpretation results for the transition zone cannot be obtained regardless of which zonal calibration type is used. In this case, a zonal calibration type can be randomly selected from the zonal calibration types corresponding to each calibration zone as the initial zonal calibration type for preliminary interpretation of the transition zone. This initial zonal calibration type is then used to automatically track and interpret the preliminary seismic stratigraphic levels in the transition zone, and the resulting information is determined as the initial stratigraphic interpretation result for the transition zone.

[0077] Following the example above, taking the zero-phase calibration type selected for the transition region as an example, Figure 7 This is an example of a stratigraphic interpretation section of the initial transition zone provided in Embodiment 2 of the present invention, as shown below. Figure 7 As shown, the cross-section it interprets is the one shown by the thick black line in the work area on the left side of the figure, H. M (x,y) represents the interpretation result of the seismic horizons after calibration and connection in this profile. It can be clearly seen that the seismic horizons in each waveform are all calibrated to the zero-phase point.

[0078] It is understood that S205 and S206 can be executed simultaneously or in any order, and this embodiment of the invention does not impose any restrictions on this. Figure 2 The example shown is based on the execution order of S205 followed by S206.

[0079] S207. Smooth the initial stratigraphic interpretation results of the transition zone to determine the stratigraphic change trend surface of the transition zone.

[0080] Specifically, the initial transition zone stratigraphic interpretation results are smoothed using methods such as Laplace filtering, and the fluctuating initial transition zone stratigraphic interpretation results are calculated into an approximate plane, which is then determined as the transition zone stratigraphic change trend surface.

[0081] It is understood that the parameters selected during the smoothing process will affect the details of the final recovered layer. Through continuous iterative parameter experiments, the resulting transition zone layer change trend surface can be made to approximate a plane. This embodiment of the invention does not limit the algorithm and parameter selection method used for smoothing.

[0082] S208. The difference between the initial stratigraphic interpretation results of the transition zone and the stratigraphic change trend surface of the transition zone is determined as the transition zone difference surface.

[0083] Specifically, since the transition zone stratigraphic change trend surface only retains the basic stratigraphic change trend in the transition zone after smoothing, the detailed features of stratigraphic undulation are weakened. Although the initial stratigraphic interpretation results in the transition zone cannot accurately identify the stratigraphic layers in the transition zone, they still provide a detailed interpretation of the stratigraphic undulation details. At this time, by subtracting the initial stratigraphic interpretation results from the transition zone stratigraphic change trend surface, the weakened stratigraphic undulation details in the transition zone stratigraphic change trend surface can be retained in the transition zone difference surface, thus achieving the preservation of geological details and stratigraphic undulation details in the transition zone.

[0084] For example, suppose the transition zone stratigraphic trend surface is represented by S0(x,y), and the initial transition zone stratigraphic interpretation result is represented by H. M (x,y) represents the transition region difference surface, which can then be expressed as:

[0085] ΔS(x,y)=H M (x,y)-S0(x,y)

[0086] S209. Based on the synthetic seismic records corresponding to the well data of each well, determine the time difference parameters between the calibration types of each calibration area.

[0087] Specifically, based on the synthetic seismic records corresponding to the well data of each well, the waveforms corresponding to the seismic traces in each synthetic seismic record can be determined. Since the calibration type of each calibration area represents the location of the calibration point on the waveform, the time difference between the location points of each calibration type on the waveform can be determined for each well. By combining the time differences in the synthetic seismic records corresponding to all wells in the work area, the time difference parameters between the calibration types of each calibration area can be obtained.

[0088] For example, suppose the time difference between the corresponding positions of two zone calibration types in the waveform of the synthetic seismic record of the i-th well in the work area can be expressed as Δt. iThen the time difference parameter can be expressed as:

[0089]

[0090] Where N represents the number of wells in the work area; In this embodiment of the invention, two calibration types are used as examples: trough calibration type and - / + zero phase calibration type. Let be the trough time in the synthetic seismic record of the i-th well. is the zero-phase time in the synthetic seismic record of the i-th well.

[0091] S210. The sum of the time difference parameter and the transition zone stratigraphic change trend surface is determined as the rotation target trend surface.

[0092] Specifically, the stratigraphic change trend surface in the transition zone is determined based on either of the two calibration types, and it appears as an approximately straight line on the cross-section. The purpose of rotating this trend surface is to align the boundaries of the stratigraphic levels in the two different calibration zones. This is achieved by fixing one side of the trend surface and raising (or lowering) the other side to complete the spatial rotation. Therefore, it is necessary to first determine the target position to which the other side of the stratigraphic change trend surface needs to be rotated. The stratigraphic change trend surfaces corresponding to the two different calibration types can be considered as two approximately parallel straight lines on the cross-section. Therefore, the target rotation trend surface can be obtained by summing the transition zone stratigraphic change trend surface with the time difference parameter.

[0093] Following the example above, the rotation target trend surface can be characterized as: S1(x,y)=S0(x,y)+Δt.

[0094] S211. Construct a rotation trend surface with the transition zone layer change trend surface as the starting state and the rotation target trend surface as the target state.

[0095] Following the example above, since the rotation target trend surface S1(x,y) and the transition zone stratum change trend surface S0(x,y) are two parallel trend surfaces, they can be displayed as two parallel strata on the cross section. In this embodiment of the invention, a cross section spanning the transition zone is taken as an example to explain the method of generating a rotation trend surface with the transition zone stratum change trend surface as the starting state and the rotation target trend surface as the target state. Figure 8 This is an example diagram illustrating the conversion process of a rotation trend surface according to Embodiment 2 of the present invention. Taking a transition zone stratigraphic change trend surface of the - / +zero phase calibration type and a target rotation trend surface of the trough calibration type as an example, it is assumed that... Figure 8The two endpoints of the transition zone stratigraphic change trend surface S0(x,y) are A0(x,y,t) and B0(x,y,t), and the two endpoints of the rotation target trend surface S1(x,y) are A1(x,y,t) and B1(x,y,t). Here, A0(x,y,t) represents the starting point of the trend surface calibrated by - / + zero phase, and B0(x,y,t) represents the ending point of the trend surface calibrated by - / + zero phase; A1(x,y,t) represents the starting point of the trough calibration trend surface, and B1(x,y,t) represents the ending point of the trough calibration trend surface. The trend surface construction method, which uses the transition zone stratigraphic change trend surface as the starting state and the rotation target trend surface as the target state, is essentially creating new trend surfaces from multiple profiles, starting at A0(x,y,t) and ending at B1(x,y,t). In other words, the obtained rotation trend surface S2(x,y) can be considered as a plane obtained by taking sections of the transition zone at appropriate section intervals, connecting A0(x,y,t) and B1(x,y,t) with straight stratigraphic planes on each section, and then using interpolation to make the stratigraphic difference into a plane.

[0096] S212. The sum of the rotation trend surface and the transition zone difference surface is determined as the stratigraphic interpretation result of the transition zone.

[0097] Specifically, after identifying the rotational trend surface in the transition zone that allows for a smooth transition between the stratigraphic positions of the two calibration zones, geological details and stratigraphic undulation details in the transition zone can be superimposed on this rotational trend surface. In other words, the rotational trend surface and the difference surface of the transition zone can be summed, and the resulting plane can be determined as the stratigraphic interpretation result of the transition zone.

[0098] S213. Combine the stratigraphic interpretation results of each calibration zone with the stratigraphic interpretation results of the transition zone to determine the seismic stratigraphic interpretation results of the work area.

[0099] It is understandable that, since the interpretation results of each calibration zone and the interpretation results of the transition zone can be accurately connected without overlap based on the determined boundary of the transition zone, and since there are no extreme values ​​for the interpretation of the layer at the connection position, ordinary layer splicing or synthesis methods can be used to splice the interpretation results of each layer. The embodiments of the present invention will not be described in detail here.

[0100] The technical solution of this embodiment constructs a synthetic seismic record for each well using well data acquired within the work area. The synthetic seismic record is then calibrated using accurate stratigraphic information contained in the well data, which is relevant to the seismic horizon interpretation required, to accurately determine the well calibration type for each well. Based on different well calibration types, each well is divided into regions. Between wells with transitional calibration types and those without, the geological boundary lines are analyzed to determine the transition zone boundary between the calibration interval and the transition zone boundary. Finally, based on the transition zone boundary line and the work area boundary line, the entire work area is precisely divided into a transition zone and two calibration zones. After completing the preliminary interpretation of the transition zone and the automatic interpretation of the calibration zone based on the calibration type of each calibration zone, the difference between the initial transition zone stratigraphic interpretation result and the transition zone stratigraphic change trend surface obtained by smoothing the initial transition zone stratigraphic interpretation result is used to obtain the transition zone difference surface that preserves the stratigraphic undulation details in the transition zone. Then, based on the well data of each well and the calibration type of each calibration zone, the time difference parameter required for stratigraphic change rotation is determined. Based on the time difference parameter, the transition zone stratigraphic change trend surface is rotated to obtain the rotation target trend surface that can make the change trend transition smoothly. Then, the rotation target trend surface is superimposed with the transition zone difference surface that preserves the stratigraphic undulation details as the transition zone stratigraphic interpretation result. This ensures that the transition zone stratigraphic interpretation result can retain sufficient stratigraphic undulation details and enable a smooth transition between adjacent calibration zones for stratigraphic calibration. Furthermore, the accuracy of the boundary delineation of the transition zone improves the splicing accuracy of the stratigraphic interpretation results of each calibration zone with those of the transition zone, thereby enhancing the accuracy of the overall seismic stratigraphic interpretation of the work area and the degree of preservation of geological details, thus meeting the oilfield exploration demand for high-precision interpretation results.

[0101] Example 3

[0102] Figure 9 This is a schematic diagram of the structure of a seismic horizon interpretation device provided in Embodiment 3 of the present invention, as shown below. Figure 9 As shown, the seismic horizon interpretation device includes a calibration zone determination module 31, a calibration result determination module 32, a transition result determination module 33, and a work area result determination module 34.

[0103] The calibration area determination module 31 is used to determine the well calibration type of each well based on the well data of all wells in the work area, and divide the work area into a transition zone and two calibration zones according to the well calibration type of each well; wherein, the zone calibration type of each calibration zone is the well calibration type of the wells in the calibration zone; the calibration result determination module 32 is used to perform stratigraphic tracking on the transition zone and the corresponding calibration zone according to the zone calibration type of each calibration zone, and determine the initial stratigraphic interpretation result of the transition zone and the stratigraphic interpretation result of the corresponding calibration zone of each calibration zone; the transition result determination module 33 is used to perform stratigraphic change rotation on the initial stratigraphic interpretation result of the transition zone according to the zone calibration type of each calibration zone and the well data of each well, and determine the stratigraphic interpretation result of the transition zone; the work area result determination module 34 is used to splice the stratigraphic interpretation results of each calibration zone with the stratigraphic interpretation results of the transition zone to determine the seismic stratigraphic interpretation result of the work area.

[0104] The fault zone identification device provided in this embodiment of the invention can execute the fault zone identification method provided in any embodiment of the invention, and has the corresponding functional modules and beneficial effects of the method.

[0105] The technical solution of this invention will first determine the well calibration type required for calibrating the strata in different wells based on the well data of the completed stratigraphic determination in the work area, and then divide the work area into regions according to the different well calibration types to obtain calibration areas that can be automatically tracked and interpreted by seismic stratigraphy through clear calibration standards, and transition areas located between different calibration areas that cannot be automatically tracked and interpreted by seismic stratigraphy through clear calibration standards. For the calibration area, an automatic seismic stratigraphic tracking method corresponding to the calibration type of the calibration area is used to process it to obtain the stratigraphic interpretation results for the calibration area. For the transition area, the initial stratigraphic interpretation results obtained from the preliminary processing in the transition area are rotated based on the calibration type of the surrounding calibration areas and well data throughout the entire work area. This allows the rotated stratigraphic interpretation results of the transition area to smoothly transition and connect with the stratigraphic interpretation results of the calibration area at the boundary of the calibration area. Within the transition area, the interpreted stratigraphic results are gradually transitioned from the stratigraphic interpretation results of one calibration area to the stratigraphic interpretation results of the other calibration area. During this transition process, as much detail of stratigraphic undulations in the transition area as possible is preserved. After completing the stratigraphic interpretation of the transition area, the stratigraphic interpretation results of the transition area are stitched together with the stratigraphic interpretation results of each calibration area to obtain the seismic stratigraphic interpretation results of the entire work area. This improves the accuracy of the overall seismic stratigraphic interpretation of the work area and the degree of geological detail preservation, meeting the needs of oilfield exploration for high-precision interpretation results.

[0106] Optionally, the calibration area determination module 31 is specifically used for:

[0107] Obtain well data for all wells within the work area;

[0108] For each well, accurate stratification information and synthetic seismic records are determined based on well data, and the synthetic seismic records are calibrated using the accurate stratification information to determine the well calibration type.

[0109] The geological boundary between wells with a transitional calibration type and wells with a non-transitional calibration type is defined as the boundary line of the transition zone.

[0110] Based on the boundary lines of the work area and the transition area, the work area is divided into a transition area and two calibration areas.

[0111] Optional geological boundaries include at least one of the following:

[0112] Lithological variation trend line;

[0113] pinch-out line of overlying strata;

[0114] Pinch-out line of the underlying strata;

[0115] Lines showing variations in stratigraphic thickness;

[0116] Special geological structural lines.

[0117] Optionally, the calibration result determination module 32 is specifically used for:

[0118] For each calibration area, perform stratigraphic tracing corresponding to the calibration type of the calibration area to determine the stratigraphic interpretation result of the calibration area;

[0119] Choose one of the calibration types from each calibration area as the initial calibration type for the transition area, and perform stratigraphic tracing in the transition area corresponding to the initial calibration type to determine the stratigraphic interpretation result of the initial transition area.

[0120] Optionally, the transition result determination module 33 is specifically used for:

[0121] The initial stratigraphic interpretation results of the transition zone are smoothed to determine the stratigraphic trend surface of the transition zone.

[0122] The difference between the initial stratigraphic interpretation results of the transition zone and the stratigraphic change trend surface of the transition zone is defined as the transition zone difference surface;

[0123] Based on the synthetic seismic records corresponding to the well data of each well, the time difference parameters between the calibration types of each calibration area are determined;

[0124] The sum of the time difference parameter and the transition zone stratigraphic change trend surface is determined as the rotation target trend surface;

[0125] Construct a rotation trend surface with the transition zone layer change trend surface as the starting state and the rotation target trend surface as the target state;

[0126] The sum of the rotation trend surface and the transition zone difference surface is determined as the stratigraphic interpretation result of the transition zone.

[0127] The seismic horizon interpretation device provided in this embodiment of the invention can execute the seismic horizon interpretation method provided in any embodiment of the invention, and has the corresponding functional modules and beneficial effects of the method execution.

[0128] Example 4

[0129] Figure 10 This is a schematic diagram of a seismic horizon interpretation device provided in Embodiment 4 of the present invention. The seismic horizon interpretation device 40 can represent various forms of digital computers, such as laptop computers, desktop computers, workbenches, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The seismic horizon interpretation device 40 can also represent various forms of mobile devices, such as personal digital assistants, cellular phones, smartphones, wearable devices (such as helmets, glasses, watches, etc.), and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely illustrative and are not intended to limit the implementation of the invention described and / or claimed herein.

[0130] like Figure 10 As shown, the seismic horizon interpretation device 40 includes at least one processor 41 and a memory, such as a read-only memory (ROM) 42 and a random access memory (RAM) 43, communicatively connected to the at least one processor 41. The memory stores programmable programs executable by the at least one processor. The processor 41 can perform various appropriate actions and processes based on the programmable program stored in the ROM 42 or loaded from storage unit 48 into the RAM 43. The RAM 43 can also store various programs and data required for the operation of the seismic horizon interpretation device 40. The processor 41, ROM 42, and RAM 43 are interconnected via a bus 44. An input / output (I / O) interface 45 is also connected to the bus 44. Optionally, the processor can be an FPGA.

[0131] Multiple components in the seismic horizon interpretation device 40 are connected to the I / O interface 45, including: an input unit 46, such as a keyboard, mouse, etc.; an output unit 47, such as various types of displays, speakers, etc.; a storage unit 48, such as a disk, optical disk, etc.; and a communication unit 49, such as a network card, modem, wireless transceiver, etc. The communication unit 49 allows the seismic horizon interpretation device 40 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0132] Processor 41 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of processor 41 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various special-purpose artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any suitable processor, controller, microcontroller, etc. Processor 41 performs the various methods and processes described above, such as seismic horizon interpretation methods.

[0133] In some embodiments, the seismic horizon interpretation method may be implemented as a programmable program tangibly contained in a computer-readable storage medium, such as storage unit 48. In some embodiments, part or all of the programmable program may be loaded and / or installed onto the seismic horizon interpretation device 40 via ROM 42 and / or communication unit 49. When the programmable program is loaded into RAM 43 and executed by processor 41, one or more steps of the seismic horizon interpretation method described above may be performed. Alternatively, in other embodiments, processor 41 may be configured to perform the seismic horizon interpretation method by any other suitable means (e.g., by means of firmware).

[0134] Optionally, embodiments of the present invention also provide a computer program product, including a computer program that, when executed by a processor, implements the seismic horizon interpretation method as provided in any embodiment of the present invention.

[0135] Various embodiments of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), application-specific standard products (ASSPs), systems-on-a-chip (SoCs), payload-programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments may include implementations in one or more programmable programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which may be a dedicated or general-purpose programmable processor, capable of receiving data and instructions from a memory system, at least one input device, and at least one output device, and transmitting data and instructions to the memory system, the at least one input device, and the at least one output device.

[0136] Programmable programs for implementing the methods of the present invention can be written in any combination of one or more programming languages. These programmable programs can be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, such that when executed by the processor, the programmable programs cause the functions / operations specified in the flowcharts and / or block diagrams to be implemented. The programmable programs can be executed entirely on a machine, partially on a machine, as a standalone software package partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

[0137] In the context of this invention, a computer-readable storage medium can be a tangible medium that may contain or store a programmable program for use by or in conjunction with an instruction execution system, apparatus, or device. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatus, or devices, or any suitable combination thereof. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. More specific examples of machine-readable storage media include electrical connections based on one or more wires, portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fibers, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination thereof.

[0138] To provide user interaction, the systems and techniques described herein can be implemented on a seismic horizon interpretation device, which includes: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and pointing device (e.g., a mouse or trackball) through which the user provides input to the seismic horizon interpretation device. Other types of devices can also be used to provide user interaction; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including sound input, voice input, or tactile input).

[0139] The systems and technologies described herein can be implemented in computing systems that include backend components (e.g., as data servers), or computing systems that include middleware components (e.g., application servers), or computing systems that include frontend components (e.g., user computers with graphical user interfaces or web browsers through which users can interact with implementations of the systems and technologies described herein), or any combination of such backend, middleware, or frontend components. The components of the system can be interconnected via digital data communication of any form or medium (e.g., communication networks). Examples of communication networks include local area networks (LANs), wide area networks (WANs), blockchain networks, and the Internet.

[0140] A computing system can include clients and servers. Clients and servers are generally geographically separated and typically interact via communication networks. The client-server relationship is created by programmable programs running on the respective computers and having a client-server relationship with each other. The server can be a cloud server, also known as a cloud computing server or cloud host, which is a hosting product within the cloud computing service system to address the shortcomings of traditional physical hosts and VPS services, such as high management difficulty and weak business scalability.

[0141] It should be understood that the various forms of processes shown above can be used, with steps reordered, added, or deleted. For example, the steps described in this invention can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution of this invention can be achieved, and this is not limited herein.

[0142] The specific embodiments described above do not constitute a limitation on the scope of protection of this invention. Those skilled in the art should understand that various modifications, combinations, sub-combinations, and substitutions can be made according to design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of this invention should be included within the scope of protection of this invention.

Claims

1. A method for interpreting seismic horizons, characterized in that, include: The well calibration type of each well is determined based on the well data of all wells in the work area, and the work area is divided into a transition zone and two calibration zones according to the well calibration type of each well; wherein, the zone calibration type of each calibration zone is the well calibration type of the wells in the calibration zone; Based on the calibration type of each calibration area, the transition area and the corresponding calibration area are subjected to layer tracing to determine the initial transition area layer interpretation result and the corresponding calibration area layer interpretation result of each calibration area. Based on the calibration type of each calibration area and the well data of each well, the initial transition zone stratigraphic interpretation results are rotated to determine the transition zone stratigraphic interpretation results; The stratigraphic interpretation results of each calibration zone are combined with the stratigraphic interpretation results of the transition zone to determine the seismic stratigraphic interpretation results of the work area.

2. The seismic horizon interpretation method according to claim 1, characterized in that, The process of determining the well calibration type of each well based on well data from all wells within the work area, and dividing the work area into a transition zone and two calibration zones based on the well calibration type of each well, includes: Obtain well data for all wells within the work area; For each well, accurate stratification information and synthetic seismic records are determined based on the well data, and the synthetic seismic records are calibrated using the accurate stratification information to determine the well calibration type.

3. The seismic horizon interpretation method according to claim 1, characterized in that, The division of the work area into a transition zone and two calibration zones based on the well calibration type of each well includes: The geological boundary between wells whose well calibration type is transitional and wells whose well calibration type is not transitional is defined as the boundary line of the transition zone. Based on the boundary line of the work area and the boundary line of the transition area, the work area is divided into a transition area and two calibration areas.

4. The seismic horizon interpretation method according to claim 3, characterized in that, The geological boundary line includes at least one of the following: Lithological variation trend line; pinch-out line of overlying strata; Pinch-out line of the underlying strata; Stratigraphic thickness variation line; Special geological structural lines.

5. The seismic horizon interpretation method according to claim 1, characterized in that, The step of performing layer tracing on the transition region and the corresponding calibration region according to the region calibration type of each calibration region, and determining the initial transition region layer interpretation result and the corresponding calibration region layer interpretation result of each calibration region, includes: For each calibration region, perform stratigraphic tracing corresponding to the region calibration type of the calibration region to determine the calibration region stratigraphic interpretation result of the calibration region; Choose one of the calibration types from each calibration region as the initial calibration type of the transition region, and perform layer tracing on the transition region corresponding to the initial calibration type to determine the initial transition region layer interpretation result.

6. The seismic horizon interpretation method according to claim 2, characterized in that, The step of performing stratigraphic variation rotation on the initial transition zone stratigraphic interpretation results based on the zone calibration type of each calibration zone and the well data of each well to determine the transition zone stratigraphic interpretation results includes: The initial stratigraphic interpretation results of the transition zone are smoothed to determine the stratigraphic change trend surface of the transition zone; The difference between the initial transition zone stratigraphic interpretation result and the transition zone stratigraphic change trend surface is determined as the transition zone difference surface; Based on the synthetic seismic records corresponding to the well data of each well, determine the time difference parameters between the calibration types of each calibration area; The sum of the time difference parameter and the transition zone stratigraphic change trend surface is determined as the rotation target trend surface; Construct a rotation trend surface with the transition zone layer change trend surface as the starting state and the rotation target trend surface as the target state; The sum of the rotation trend surface and the transition zone difference surface is determined as the layer interpretation result of the transition zone.

7. A seismic horizon interpretation device, characterized in that, include: The calibration zone determination module is used to determine the well calibration type of each well based on the well data of all wells in the work area, and to divide the work area into a transition zone and two calibration zones based on the well calibration type of each well; wherein, the zone calibration type of each calibration zone is the well calibration type of the wells in the calibration zone; The calibration result determination module is used to perform layer tracing on the transition region and the corresponding calibration region according to the region calibration type of each calibration region, and to determine the initial transition region layer interpretation result and the corresponding calibration region layer interpretation result of each calibration region; The transition result determination module is used to perform stratigraphic change rotation on the initial transition zone stratigraphic interpretation result based on the zone calibration type of each calibration zone and the well data of each well, and to determine the transition zone stratigraphic interpretation result. The work area result determination module is used to combine the stratigraphic interpretation results of each calibration zone with the stratigraphic interpretation results of the transition zone to determine the seismic stratigraphic interpretation results of the work area.

8. A seismic horizon interpretation device, characterized in that, include: At least one processor; and a memory communicatively connected to the at least one processor; The memory stores a programmable program that can be executed by the at least one processor, which is then executed by the at least one processor to enable the at least one processor to perform the seismic horizon interpretation method according to any one of claims 1-6.

9. A storage medium containing computer-executable instructions, characterized in that, The computer-executable instructions, when executed by a computer processor, are used to perform the seismic horizon interpretation method as described in any one of claims 1-6.

10. A computer program product comprising a computer program, which, when executed by a processor, performs the seismic horizon interpretation method as described in any one of claims 1-6.

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