Deposition microfacies determination method, device, equipment, medium and product

Abstract

The invention discloses a sedimentary microfacies determination method, device and equipment, a medium and a product. According to the specific scheme, a target layer group range of a target drilled well is determined, and a target layer section is determined according to the target layer group range; analyzing and processing the profile map of the target layer section according to the three-dimensional seismic data, determining seismic response characteristics of the target layer section, and determining seismic horizon data of the target layer section according to the seismic response characteristics; according to the seismic horizon data, the ancient landform of the target layer section is subjected to restoration processing, and an ancient landform image of the target layer section in the deposition period is obtained; based on the heavy mineral analysis parameter, the stratigraphic dip angle parameter and the ancient landform image of at least one drilled well of the target area to which the target drilled well belongs in the target interval, determining an ancient channel plane distribution diagram of the target interval; and determining a fine sedimentary microfacies diagram of the target layer section according to the seismic horizon data and the paleochannel plane distribution diagram. According to the method, the accuracy of determining the sedimentary microfacies is improved, and the cost is saved for subsequent exploration and development.

Description

Technical Field

[0001] This invention relates to the field of image processing technology, and in particular to a method, apparatus, device, medium, and product for determining depositional microphases. Background Technology

[0002] Sedimentary microfacies refer to the smallest units within a subfacies zone that possess unique lithological structures, textures, thicknesses, rhythmic characteristics, and certain planar configurations. The identification of sedimentary microfacies has a significant impact on oil and gas exploration and development.

[0003] Currently, the methods for determining sedimentary microfacies are usually based on drilling data and human experience. However, these methods are inaccurate when predicting the thickness of interfluvial sand bodies, meaning they cannot accurately determine sedimentary microfacies. This, in turn, affects subsequent oil and gas exploration and development. Summary of the Invention

[0004] This invention provides a method, apparatus, equipment, medium, and product for determining sedimentary microfacies, which improves the accuracy of sedimentary microfacies determination and saves costs for subsequent exploration and development.

[0005] According to one aspect of the present invention, a method for determining sedimentary microfacies is provided, the method comprising:

[0006] Determine the target formation range of the target well, and determine the target formation segment based on the target formation range;

[0007] Based on the analysis and processing of the profile diagram of the target layer using 3D seismic data, the seismic response characteristics of the target layer are determined, and the seismic horizon data of the target layer are determined based on the seismic response characteristics.

[0008] Based on the seismic stratigraphic data, the paleogeomorphology of the target stratigraphic segment is restored, and the paleogeomorphological image of the target stratigraphic segment during the depositional period is obtained.

[0009] Based on the heavy mineral analysis parameters and stratigraphic dip parameters of at least one drilled well in the target area to which the target well belongs, and paleogeographic images, determine the paleochannel plan distribution map of the target stratigraphic segment;

[0010] Based on seismic stratigraphic data and paleochannel planar distribution maps, a detailed sedimentary microfacies map of the target stratigraphic segment was determined.

[0011] According to another aspect of the present invention, a depositional microphase determination apparatus is provided, the apparatus comprising:

[0012] The target formation determination module is used to determine the target formation range of the target well and to determine the target formation based on the target formation range.

[0013] The seismic horizon data determination module is used to analyze and process the profile of the target horizon based on 3D seismic data, determine the seismic response characteristics of the target horizon, and determine the seismic horizon data of the target horizon based on the seismic response characteristics.

[0014] The paleogeomorphology image determination module is used to reconstruct the paleogeomorphology of the target layer based on seismic stratigraphic data, and obtain the paleogeomorphology image of the target layer during the depositional period.

[0015] The paleochannel plan distribution map determination module is used to determine the paleochannel plan distribution map of the target layer based on the heavy mineral analysis parameters and stratigraphic dip parameters of at least one drilled well in the target area to which the target well belongs, and paleogeographic images.

[0016] The sedimentary microfacies map determination module is used to determine the fine sedimentary microfacies map of the target layer based on seismic stratigraphic data and paleochannel planar distribution maps.

[0017] According to another aspect of the present invention, an electronic device is provided, the electronic device comprising:

[0018] At least one processor; and

[0019] A memory that is communicatively connected to at least one processor; wherein,

[0020] The memory stores a computer program that can be executed by at least one processor, such that the at least one processor is able to perform the deposition microphase determination method of any embodiment of the present invention.

[0021] According to another aspect of the present invention, a computer-readable storage medium is provided that stores computer instructions for causing a processor to execute and implement the depositional microphase determination method of any embodiment of the present invention.

[0022] According to another aspect of the present invention, a computer program product is provided, comprising a computer program, characterized in that the computer program, when executed by a processor, implements a deposition microphase determination method as described in any embodiment of the present invention.

[0023] The technical solution of this invention provides accurate study sections for subsequent processing by determining the target stratigraphic range of the target well and identifying the target stratigraphic segment based on the target stratigraphic range. Based on the analysis and processing of the profile map of the target stratigraphic segment using 3D seismic data, the seismic response characteristics of the target stratigraphic segment are determined, and the seismic horizon data of the target stratigraphic segment is determined based on the seismic response characteristics. The paleogeomorphological reconstruction of the target stratigraphic segment is performed based on the seismic horizon data to obtain a paleogeomorphological image of the target stratigraphic segment during the depositional period. Based on the heavy mineral analysis parameters and stratigraphic dip parameters of at least one drilled well in the target area to which the target well belongs, combined with the paleogeomorphological image, the paleochannel planar distribution map of the target stratigraphic segment is determined, and the depositional range of channel sand bodies is determined based on the paleochannel planar distribution map. A fine sedimentary microfacies map of the target stratigraphic segment is determined based on the seismic horizon data and the paleochannel planar distribution map. Sand body planar prediction is performed using the seismic inversion map and seismic sensitivity attribute prediction map corresponding to the seismic horizon data, as well as the paleochannel planar distribution map, improving the prediction accuracy. Based on this, an accurate and detailed sedimentary microfacies map was determined, which solved the problem of insufficient accuracy and efficiency in the sedimentary microfacies determination process, improved the accuracy of sedimentary microfacies determination, and saved costs for subsequent exploration and development.

[0024] 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

[0025] 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.

[0026] Figure 1 This is a flowchart of a method for determining depositional microphases provided in an embodiment of the present invention;

[0027] Figure 2 This is an example diagram of the short-term cycle division of the AH12 drilling section provided in an embodiment of the present invention;

[0028] Figure 3 This is an example diagram of a cross-sectional view of a target layer provided in an embodiment of the present invention;

[0029] Figure 4 This is an example image of paleogeographical features from the depositional period provided in an embodiment of the present invention;

[0030] Figure 5 This is a flowchart of a method for determining depositional microphases provided in an embodiment of the present invention;

[0031] Figure 6 This is an example diagram of the ancient river channel plan distribution provided in an embodiment of the present invention;

[0032] Figure 7 This is an example diagram of the seismic inversion diagram provided in an embodiment of the present invention;

[0033] Figure 8 This is an example diagram of the earthquake sensitivity attribute prediction map provided in an embodiment of the present invention;

[0034] Figure 9 This is an example diagram of a fine depositional microphase diagram provided in an embodiment of the present invention;

[0035] Figure 10 This is a schematic diagram of a deposition microphase determination device provided in an embodiment of the present invention;

[0036] Figure 11 This is a schematic diagram of the structure of an electronic device that implements the deposition microphase determination method of the present invention. Detailed Implementation

[0037] 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.

[0038] 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 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.

[0039] Example 1

[0040] Figure 1This is a flowchart of a sedimentary microfacies determination method provided in Embodiment 1 of the present invention. This embodiment is applicable to situations requiring fine determination of sedimentary microfacies at a target depth in drilling. The method can be executed by a sedimentary microfacies determination device, which can be implemented in hardware and / or software. This device can be configured in electronic devices such as mobile phones, computers, or servers. Figure 1 As shown, the method includes:

[0041] S110. Determine the target formation range of the target well and determine the target formation segment based on the target formation range.

[0042] The target area can be a currently selected region for studying sedimentary microfacies. This target area includes multiple wells, each with similar treatment. Therefore, the currently selected well can be used as the target well. Optionally, based on the well information corresponding to each well within the target area, wells with more distinct drilling characteristics can be selected as target wells. Dividing the target wells yields at least one layer group. The target layer group range can be selected from at least one layer group range. Optionally, since the oil and gas producing points differ for each layer group range, the layer group range with a higher distribution of oil and gas producing points is used as the target layer group range. Here, an oil and gas producing point refers to the specific location in an oil and gas reservoir where oil and gas can flow out naturally or be extracted through artificial methods.

[0043] The stratigraphic segment can be obtained by dividing the target stratigraphic group's range based on its lithological characteristics and well logging characteristics. Lithological characteristics may include the main rock types and grain size variations corresponding to the target stratigraphic group's range. Well logging characteristics may include the resistivity and sonic transit time of the well logging curves corresponding to the target stratigraphic group's range. Dividing the target stratigraphic group's range yields at least one stratigraphic segment. The target stratigraphic segment can be selected from at least one segment. Optionally, the target stratigraphic segment can be a segment with a high concentration of oil and gas producing points.

[0044] Specifically, the target well is divided into at least one layer group. Since the distribution of oil and gas producing points differs across different layer groups, the layer group with a higher concentration of oil and gas producing points can be designated as the target layer group. Based on the lithological characteristics and logging curves of the target layer group in the drilling data, the target layer group is further divided into at least one segment. Correspondingly, the distribution of oil and gas producing points differs across each segment; therefore, the segment with a higher concentration of oil and gas producing points can be designated as the target segment for sedimentary microfacies studies.

[0045] In this embodiment of the invention, the method for determining the target layer may be as follows: dividing the target well based on the short-term cycle division method to obtain at least one candidate layer group range; determining the target layer group range based on the oil and gas production properties within the at least one candidate layer group range; dividing the target layer group range based on the short-term cycle division method to obtain at least one candidate sand group; determining the target sand group based on the oil and gas production properties of the at least one candidate sand group, and using the target sand group as the target layer.

[0046] In defining the target well and target formation range, a short-cycle partitioning method can be used. Short-cycle partitioning divides the target well or target formation range into smaller stratigraphic units. The candidate formation range can be the range obtained by performing short-cycle partitioning on the target well. There can be one or more candidate formation ranges. For example, taking well AH12 as the target well, short-cycle partitioning of well AH12 yields three candidate formation ranges. Oil and gas production attributes can be understood as the number of oil and gas producing points. The target formation range can be the candidate formation range with a high distribution of oil and gas producing points. Candidate sand groups can be sand groups defined based on the lithological characteristics and logging curve characteristics of the target formation range. There can be one or more candidate sand groups. The target sand group can be understood as the candidate sand group with a high distribution of oil and gas producing points. The target interval is the target sand group.

[0047] Specifically, the target well is divided into short-term cycles to obtain at least one candidate layer range. Based on the oil and gas production attributes within each candidate layer range, the candidate layer range with the highest concentration of oil and gas production points is designated as the target layer range. The target layer range is further divided into short-term cycles based on its lithological characteristics and logging curve characteristics to obtain at least one candidate sand group. Based on the oil and gas production attributes corresponding to each candidate sand group, the candidate sand group with the highest concentration of oil and gas production points is identified as the target sand group, and this target sand group is designated as the target interval.

[0048] For example, the AH12 well within the target area is used as an example. Short-term cycle division of the AH12 well yields three sections: Section 1, Section 2, and Section 3. Since the distribution of oil and gas producing points differs across different stratigraphic units, Section 1 of the AH12 well, with more producing points, can be selected as the target stratigraphic unit. The lithology of the target stratigraphic unit is primarily composed of interbedded gray conglomerate, gray fine sandstone, silty mudstone, and gray mudstone, vertically composed of multiple superimposed cycles, exhibiting an overall positive gradation characteristic of finer grains at the top and coarser grains at the bottom. Based on the lithological characteristics and logging curves of the target stratigraphic unit, short-term cycle division of Section 1 of the AH12 well yields four phases of channel sand body deposition: Phase I, Phase II, Phase III, and Phase IV. That is, the first sand group of section 1 of drilling AH12, the second sand group of section 1 of drilling AH12, the third sand group of section 1 of drilling AH12, and the fourth sand group of section 1 of drilling AH12. For example... Figure 2 As shown, Figure 2 Example diagram of four sand groups obtained after dividing a section of the AH12 well. Figure 2 J1b1 in 1 For drilling section 1, sand group 1 of AH12, J1b1 2 For drilling section 1, sand group 2, J1b1 of AH12 3 For drilling the first section of the third sand group of AH12 and J1b1 4 This refers to the fourth sand group in section one of well AH12. Since the distribution of oil and gas production points differs for different sand groups to be selected, J1b1 can be considered... 1 As the target layer.

[0049] S120. Based on the analysis and processing of the profile of the target layer using 3D seismic data, determine the seismic response characteristics of the target layer, and determine the seismic horizon data of the target layer based on the seismic response characteristics.

[0050] In this context, 3D seismic data can be understood as the seismic information corresponding to the target segment. The profile of the target segment can be understood as a seismic profile of the target area corresponding to the target segment. Seismic response characteristics can be used to characterize features such as seismic frequency and seismic extent corresponding to the target segment. Seismic horizon data can include the top and bottom horizon data corresponding to the target segment in the seismic profile.

[0051] Specifically, based on 3D seismic data, the seismic profile of the target area corresponding to the target segment is analyzed to determine the target segment and its corresponding seismic response characteristics in the profile. Then, based on these seismic response characteristics, the seismic horizon data of the target segment is determined in the profile of the target segment.

[0052] In this embodiment of the invention, the method for determining seismic response characteristics can be: based on three-dimensional seismic data, performing fine-scale stratigraphic calibration on the profile of the target segment to obtain seismic response characteristics. Correspondingly, the method for determining seismic stratigraphic data can be: based on the seismic response characteristics, analyzing the finely calibrated stratigraphic layers to determine the seismic stratigraphic data.

[0053] Among them, fine-scale stratigraphy is used to identify and calibrate geological horizons in 3D seismic data. The fine-scale horizons in fine-scale stratigraphy, that is, the calibrated fine-scale horizons, can be understood as the top and bottom seismic layers corresponding to the target segment.

[0054] Specifically, based on the seismic information in the 3D seismic data, the seismic profile of the target area where the target segment is located is subjected to fine-grained stratigraphic calibration to obtain the seismic response characteristics corresponding to the target segment. Using high-resolution sequence stratigraphic correlation technology, the calibrated fine stratigraphic data is analyzed to determine the fine seismic stratigraphic data of the top and bottom of the target segment, i.e., the seismic stratigraphic data.

[0055] For example, see Figure 3 , Figure 3 This includes four wells: B64, AH11, B75, and AH4. Figure 3 It also includes two layers, J1b1. 1 And J1b2. Since the treatment methods are the same for different wells and formations, the following section uses J1b1 as the target formation. 1 The target well is described as AH11. Based on 3D seismic data, the seismic profile of the target area corresponding to the target layer was finely labeled to determine the target layer J1b1. 1 The corresponding seismic response characteristics. Based on... Figure 3 Drilling in the middle AH11 and the target interval J1b1 1 The location and the target layer J1b1 1 The seismic response characteristics were determined. Based on the sequence correlation principle, the target section J1b1 below well AH11 was identified. 1 The top and bottom sub-layers are used to obtain the target segment J1b1. 1 The detailed seismic horizon data at the top and bottom of the segment, i.e., seismic horizon data.

[0056] S130. Based on the seismic stratigraphic data, the paleogeography of the target stratigraphic segment is restored to obtain the paleogeographic image of the target stratigraphic segment during the depositional period.

[0057] In geological history, the sedimentary period refers to the time during which surface materials gradually accumulate on the Earth's surface or in water bodies through weathering, erosion, transportation, and deposition to form sedimentary rock layers. Paleomorphological images can be obtained by restoring and reconstructing the morphological features of the Earth's surface during the geological history corresponding to a target stratum. Paleomorphological images can be two-dimensional plans or three-dimensional models.

[0058] Specifically, seismic stratigraphic data is input into a geomorphological reconstruction model to achieve fine-grained paleogeomorphological reconstruction of the target stratigraphic segment, resulting in paleogeomorphological images of the target segment during the depositional period. These images are then used to determine the corresponding sedimentary conditions of the target stratigraphic segment. It should be noted that the geomorphological reconstruction model is specifically designed for fine-grained paleogeomorphological reconstruction of the target stratigraphic segment.

[0059] For example, see Figure 4 , Figure 4 It is the target layer J1b1 1 Paleogeographic images from the depositional period. The target stratigraphic segment is J1b1. 1 The detailed seismic horizon data of the top and bottom of the target segment are input into the geomorphological reconstruction model to perform detailed paleogeographic reconstruction of the target segment, resulting in J1b1. 1 Paleomorphological images from the depositional period.

[0060] S140. Based on the heavy mineral analysis parameters and formation dip parameters of at least one drilled well in the target area to which the target well belongs, and paleogeographic images, determine the paleochannel planar distribution map of the target layer.

[0061] The target area refers to the study area to which the target well belongs. The target area may include at least one drilled well. Drilled wells are those that have already been drilled and processed. Heavy mineral analysis parameters may include the provenance direction corresponding to the heavy mineral composition information of the target formation. Heavy mineral composition information can be understood as the content and distribution information of heavy mineral components in the target formation. Provenance direction can be understood as the direction from which the heavy mineral components originate. For example, if all drilled wells in the target area have high tin content, the provenance direction of tin can be determined by the proportion of tin content in each well. For instance, if the first drilled well has a tin content of 80%, the second drilled well has a tin content of 60%, and the third drilled well has a tin content of 40%, then the provenance direction can be determined as the direction corresponding to the location of the first drilled well, and then the locations of the second and third drilled wells. Formation dip parameters may include the channel sand body deposition area and flow direction of the target formation. The channel sand body deposition area refers to the deposition area of ​​channel sand bodies in the target formation. The direction of water flow is the paleocurrent direction of the target stratigraphic section. The paleochannel planar distribution map is used to characterize the deposition of channel sand bodies in different areas or locations corresponding to the target stratigraphic section. Since the deposition of channel sand bodies varies in different locations, different colors can be used on the paleochannel planar distribution map to represent different channel sand body deposition conditions.

[0062] Specifically, the heavy mineral composition information of at least one drilled well within the target area corresponding to the target formation is obtained. The heavy mineral composition information of at least one drilled well is analyzed to obtain the provenance direction of the target formation, which is then used as a heavy mineral analysis parameter. The river channel sand body deposition area and flow direction corresponding to at least one drilled well within the target area corresponding to the target formation are obtained, and these are used as stratigraphic dip parameters. Based on the heavy mineral analysis parameters and stratigraphic dip parameters, combined with paleogeomorphological images, a paleochannel planar distribution map of the target formation is determined.

[0063] S150. Based on seismic stratigraphic data and paleochannel planar distribution maps, determine the fine sedimentary microfacies map of the target section.

[0064] Among them, fine sedimentary microfacies maps are images used to describe the sedimentary characteristics, structure, distribution and evolution process inside channel sand bodies.

[0065] Specifically, seismic stratigraphic data is processed to image the geological characteristics of the target stratigraphic segment, resulting in a seismic inversion map. This map is used to characterize the distribution of channel sand bodies within the target stratigraphic segment. Further processing of the seismic stratigraphic data yields a seismic sensitivity attribute prediction map, which is used to determine the sand body properties and channel sand body deposition within the target stratigraphic segment. The sand body properties and depositional distribution of the target stratigraphic segment are comprehensively determined using both the seismic inversion map and the seismic sensitivity attribute prediction map. The depositional extent of channel sand bodies within the target stratigraphic segment is determined based on the paleochannel planar distribution map. By cross-validating the sand body properties, depositional distribution, and depositional extent of channel sand bodies within the target stratigraphic segment, a detailed sedimentary microfacies map of the target stratigraphic segment is obtained.

[0066] The technical solution of this embodiment provides accurate study sections for subsequent processing by determining the target stratigraphic range of the target well and then identifying the target stratigraphic segment based on the target stratigraphic range. Based on the analysis and processing of the profile map of the target stratigraphic segment using 3D seismic data, the seismic response characteristics of the target stratigraphic segment are determined, and the seismic horizon data of the target stratigraphic segment is determined based on these characteristics. Paleogeomorphic reconstruction processing of the target stratigraphic segment based on the seismic horizon data yields a paleogeomorphic image of the target stratigraphic segment during the depositional period. Based on the heavy mineral analysis parameters and stratigraphic dip parameters of at least one drilled well in the target area to which the target well belongs, combined with the paleogeomorphic image, a paleochannel planar distribution map of the target stratigraphic segment is determined, thereby determining the depositional range of channel sand bodies. A fine sedimentary microfacies map of the target stratigraphic segment is determined based on the seismic horizon data and the paleochannel planar distribution map. Sand body planar prediction is performed using the seismic inversion map and seismic sensitivity attribute prediction map corresponding to the seismic horizon data, as well as the paleochannel planar distribution map, improving prediction accuracy. Based on this, an accurate and detailed sedimentary microfacies map was determined, which solved the problem of insufficient accuracy and efficiency in the sedimentary microfacies determination process, improved the accuracy of sedimentary microfacies determination, and saved costs for subsequent exploration and development.

[0067] Example 2

[0068] Figure 5 This is a flowchart of a method for determining sedimentary microphases according to Embodiment 2 of the present invention. This embodiment is a preferred embodiment of the above embodiments. For specific implementation details, please refer to the technical solution of this embodiment. Technical terms that are the same as or corresponding to those in the above embodiments will not be repeated here. Figure 5 As shown, the method includes:

[0069] S210. Determine the target formation range of the target well and determine the target formation segment based on the target formation range.

[0070] S220. Based on the analysis and processing of the profile of the target layer using 3D seismic data, determine the seismic response characteristics of the target layer, and determine the seismic horizon data of the target layer based on the seismic response characteristics.

[0071] S230. Input the seismic stratigraphic data into the geomorphological reconstruction model, determine the geomorphological information corresponding to the target stratigraphic segment during the depositional period, and generate paleogeographic images of the target stratigraphic segment during the depositional period based on the geomorphological information.

[0072] The geomorphological reconstruction model can be a model used to reconstruct and restore the geomorphology of the target stratigraphic segment. Geomorphological information can be understood as various geomorphological information from the depositional period of the sand body corresponding to the target stratigraphic segment. For example, geomorphological information may include paleochannel information, paleolae information, and paleodun information.

[0073] Specifically, seismic stratigraphic data is input into the geomorphological reconstruction model to determine the geomorphological information corresponding to the target stratigraphic segment during the sand body deposition period. Based on the geomorphological information of the target stratigraphic segment, paleogeomorphological image restoration processing is performed to obtain the paleogeomorphological image of the target stratigraphic segment during the deposition period.

[0074] S240. Determine the heavy mineral analysis parameters and formation dip angle parameters of at least one drilled well within the target area.

[0075] The heavy mineral analysis parameters may include the provenance direction information corresponding to the target stratigraphic interval. The stratigraphic dip parameter may include the sedimentary region information and flow direction information corresponding to the target stratigraphic interval.

[0076] In this embodiment of the invention, the method for determining the heavy mineral analysis parameters and the formation dip angle parameters may be as follows: obtaining heavy mineral composition information of at least one drilled well in the target section; determining the source direction in the heavy mineral analysis parameters based on the distribution of the heavy mineral composition information in the profile of the target section; and determining the depositional area and flow direction in the formation dip angle parameters based on the formation dip angle of the target section.

[0077] The heavy mineral composition information can refer to the content of heavy minerals in the target formation from drilled wells. The provenance direction can be understood as the direction from which the heavy minerals in the target formation originate. The formation dip angle can be understood as the dihedral angle between the cross-section corresponding to the target formation and the horizontal reference plane. Since different wells are located in different geographical locations, i.e., different wells have different formation dip angles, the depositional area and flow direction in the formation dip angle parameters can be determined based on the formation dip angle. The depositional area is the area where channel sand bodies are deposited. The flow direction is the paleocurrent direction corresponding to the target formation.

[0078] Specifically, the process involves obtaining heavy mineral composition information from at least one drilled well within the target area, located in the target stratigraphic unit. By analyzing the heavy mineral composition information from different wells, the source direction of the heavy minerals, i.e., the provenance direction, is determined. The dip angle of at least one drilled well in the target stratigraphic unit is also obtained. Using the dip angle, the depositional area and flow direction within the dip angle parameters are determined. Based on the provenance direction, depositional area, and flow direction, combined with paleogeographic maps, a paleochannel planar distribution map is then determined.

[0079] S250. Based on the heavy mineral analysis parameters and formation dip parameters of at least one drilled well in the target area to which the target well belongs, and paleogeographic images, determine the paleochannel planar distribution map of the target layer.

[0080] For example, combining the above example, the heavy mineral composition information of 15 drilled wells in the target area where the target well AH11 is located is obtained in the target formation. Based on the mineral content in the heavy mineral composition information of each drilled well, the provenance direction of the target formation is determined. For example, Figure 6 The direction indicated by the red arrow is the source direction. Obtain formation dip data for 15 drilled wells in the target area where target well AH11 is located within the target formation. Based on the formation dip data of each drilled well, determine the water flow direction and depositional area of ​​the target formation. The formation dip data are as follows: Figure 6 The directional data corresponding to the small and medium-sized rectangles. Water flow direction is represented by... Figure 6 The dashed lines in the diagram represent this. Figure 6 Different colors represent channel sand body depositional areas at different depths. A detailed interpretation of the paleogeographic images is performed based on provenance direction, flow direction, and depositional area to obtain… Figure 6 The map shown depicts the distribution of ancient river channels.

[0081] S260. Based on seismic horizon data, determine the seismic inversion map and seismic sensitivity attribute prediction map of the target horizon.

[0082] The seismic inversion map is used to characterize the channel sand body deposition in the target layer. The seismic sensitivity attribute prediction map is used to characterize the sand body attribute information and channel sand body deposition distribution in the target layer.

[0083] Specifically, seismic inversion techniques are used to invert seismic stratigraphic data to obtain seismic inversion maps, which are then used to determine the distribution and deposition of channel sand bodies. For example, a seismic inversion map can be like... Figure 7 As shown. Figure 7Different colors are used to characterize the depositional status of channel sand bodies in different regions. Seismic attribute prediction techniques are used to predict the attributes of seismic stratigraphic data, resulting in a seismic sensitivity attribute prediction map. This map is then used to determine the sand body attributes and depositional distribution of channel sand bodies. For example, the seismic sensitivity attribute prediction map can be like this: Figure 8 As shown. Figure 8 Different colors are used to characterize the sedimentation of river sand bodies in different regions.

[0084] S270. Based on the seismic inversion map, seismic sensitivity attribute prediction map, and paleochannel planar distribution map, a detailed sedimentary microfacies map is determined.

[0085] Specifically, based on the channel sandbody depositional information corresponding to the seismic inversion map, the channel sandbody attributes corresponding to the seismic sensitivity attribute map, and the channel sandbody depositional information, the channel sandbody depositional distribution of the target layer is comprehensively determined, and this comprehensively determined channel sandbody depositional distribution is used as the reference sandbody depositional distribution. Since the paleochannel distribution range in the paleochannel planar distribution map corresponds to the channel sandbody depositional range, fine sedimentary microfacies can be determined based on the reference sandbody depositional distribution and the channel sandbody depositional range in the paleochannel planar distribution map, thus comprehensively determining the fine sedimentary microfacies map corresponding to the target layer. For example, the fine sedimentary microfacies map can be as follows: Figure 9 As shown, Figure 9 Different colors are used to represent the distribution of sand bodies in alluvial plains, underwater distributary channels, between distributary channels, estuary sandbars, and distal sandbars.

[0086] For example, by Figure 7 The seismic inversion map corresponding to the target layer shown is as follows: Figure 8 The seismic sensitivity attribute prediction map corresponding to the target layer shown is as follows: Figure 6 The paleochannel planar distribution map of the target stratigraphic section was used to comprehensively determine the distribution of channel sand bodies in the target stratigraphic section, thus obtaining... Figure 9 The detailed sedimentary microfacies map shown indicates that the target section belongs to the braided river delta front subfacies, and exhibits interchannel, subaqueous distributary channels, and mouth bar sedimentary microfacies. Favorable channel sand bodies covering 330 square kilometers were identified within the target area. Through targeted well location optimization, three exploratory wells were deployed, all showing good oil and gas shows, with predicted geological reserves of 160 million tons.

[0087] The technical solution of this embodiment determines the target stratigraphic range of the target well and, based on the target stratigraphic range, identifies the target stratigraphic segment, providing an accurate study segment for subsequent processing. Based on the analysis and processing of the profile of the target stratigraphic segment using 3D seismic data, the seismic response characteristics of the target stratigraphic segment are determined, and the seismic stratigraphic data of the target stratigraphic segment is determined based on these characteristics. The seismic stratigraphic data is input into a geomorphological reconstruction model to determine the geomorphological information corresponding to the target stratigraphic segment during the depositional period, and a paleogeomorphological image of the target stratigraphic segment during the depositional period is generated based on this geomorphological information. Based on this, an accurate paleogeomorphological image is obtained. Based on the heavy mineral analysis parameters and stratigraphic dip parameters of at least one drilled well within the determined target area, and the paleogeomorphological image, a paleochannel planar distribution map of the target stratigraphic segment is obtained, providing the channel sand body depositional range for determining the sedimentary microfacies of the target stratigraphic segment based on the paleochannel planar distribution map. Based on the seismic stratigraphic data, a seismic inversion map and a seismic sensitivity attribute prediction map of the target stratigraphic segment are determined, providing a reference sand body depositional distribution for determining the sedimentary microfacies of the target stratigraphic segment based on the seismic inversion map and the seismic sensitivity attribute prediction map. Based on seismic inversion maps, seismic sensitivity attribute prediction maps, and paleochannel planar distribution maps, a detailed sedimentary microfacies map was determined, which solved the problem of insufficient accuracy and efficiency in the sedimentary microfacies determination process, improved the accuracy of sedimentary microfacies determination, and saved costs for subsequent exploration and development.

[0088] Example 3

[0089] Figure 10 This is a schematic diagram of a depositional microphase determination device provided in Embodiment 3 of the present invention. Figure 10 As shown, the device includes: a target layer determination module 310, a seismic layer data determination module 320, a paleogeomorphological image determination module 330, a paleochannel plan distribution map determination module 340, and a sedimentary microfacies map determination module 350.

[0090] The target stratigraphic segment determination module 310 is used to determine the target stratigraphic group range of the target well and determine the target stratigraphic segment based on the target stratigraphic group range; the seismic horizon data determination module 320 is used to analyze and process the profile of the target stratigraphic segment based on 3D seismic data, determine the seismic response characteristics of the target stratigraphic segment, and determine the seismic horizon data of the target stratigraphic segment based on the seismic horizon data; the paleogeographic image determination module 330 is used to reconstruct the paleogeography of the target stratigraphic segment based on the seismic horizon data to obtain the paleogeographic image of the target stratigraphic segment during the depositional period; the paleochannel plan distribution map determination module 340 is used to determine the paleochannel plan distribution map of the target stratigraphic segment based on the heavy mineral analysis parameters and stratigraphic dip parameters of at least one drilled well in the target area to which the target well belongs, and the paleogeographic image; the sedimentary microfacies map determination module 350 is used to determine the fine sedimentary microfacies map of the target stratigraphic segment based on the seismic horizon data and the paleochannel plan distribution map.

[0091] The technical solution of this embodiment provides accurate study sections for subsequent processing by determining the target stratigraphic range of the target well and then identifying the target stratigraphic segment based on the target stratigraphic range. Based on the analysis and processing of the profile map of the target stratigraphic segment using 3D seismic data, the seismic response characteristics of the target stratigraphic segment are determined, and the seismic horizon data of the target stratigraphic segment is determined based on these characteristics. Paleogeomorphic reconstruction processing of the target stratigraphic segment based on the seismic horizon data yields a paleogeomorphic image of the target stratigraphic segment during the depositional period. Based on the heavy mineral analysis parameters and stratigraphic dip parameters of at least one drilled well in the target area to which the target well belongs, combined with the paleogeomorphic image, a paleochannel planar distribution map of the target stratigraphic segment is determined, thereby determining the depositional range of channel sand bodies. A fine sedimentary microfacies map of the target stratigraphic segment is determined based on the seismic horizon data and the paleochannel planar distribution map. Sand body planar prediction is performed using the seismic inversion map and seismic sensitivity attribute prediction map corresponding to the seismic horizon data, as well as the paleochannel planar distribution map, improving prediction accuracy. Based on this, an accurate and detailed sedimentary microfacies map was determined, which solved the problem of insufficient accuracy and efficiency in the sedimentary microfacies determination process, improved the accuracy of sedimentary microfacies determination, and saved costs for subsequent exploration and development.

[0092] Based on the above embodiments, optionally, the target formation segment determination module includes: a drilling division unit, used to divide the target well based on a short-term cycle division method to obtain at least one candidate formation range; a target formation range determination unit, used to determine the target formation range based on the oil and gas production properties within the at least one candidate formation range; a candidate sand group determination unit, used to divide the target formation range based on a short-term cycle division method to obtain at least one candidate sand group; and a target formation segment determination unit, used to determine the target sand group based on the oil and gas production properties of the at least one candidate sand group, and to designate the target sand group as the target formation segment.

[0093] Optionally, the seismic horizon data determination module includes: a seismic response characteristic determination unit, used to perform fine horizon calibration on the profile of the target layer based on 3D seismic data to obtain seismic response characteristics; and a seismic horizon data determination unit, used to analyze the fine horizons of the fine horizon calibration based on the seismic response characteristics to determine the seismic horizon data.

[0094] Optionally, a paleogeomorphological image determination module is used to input seismic stratigraphic data into the geomorphological reconstruction model, determine the geomorphological information corresponding to the target stratigraphic segment during the depositional period, and generate a paleogeomorphological image of the target stratigraphic segment during the depositional period based on the geomorphological information.

[0095] Optionally, the device further includes: a heavy mineral analysis parameter and formation dip angle parameter determination module, which is used to acquire heavy mineral composition information of at least one drilled well in the target section; determine the source direction in the heavy mineral analysis parameters based on the distribution of heavy mineral composition information in the profile of the target section; and determine the sedimentary area and water flow direction in the formation dip angle parameters based on the formation dip angle of the target section.

[0096] Optionally, a sedimentary microfacies map determination module is used to determine the seismic inversion map and seismic sensitivity attribute prediction map of the target layer based on seismic stratigraphic data; and to determine the fine sedimentary microfacies map based on the seismic inversion map, seismic sensitivity attribute prediction map and paleochannel planar distribution map.

[0097] The depositional microphase determination device provided in the embodiments of the present invention can execute the depositional microphase determination method provided in any embodiment of the present invention, and has the corresponding functional modules and beneficial effects of the method.

[0098] Example 4

[0099] Figure 11 This is a schematic diagram of the structure of an electronic device provided in Embodiment 4 of the present invention. The electronic device 10 is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device may also represent various forms of mobile devices, such as personal digital processors, 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.

[0100] like Figure 11 As shown, the electronic device 10 includes at least one processor 11 and a memory, such as a read-only memory (ROM) 12 or a random access memory (RAM) 13, communicatively connected to the at least one processor 11. The memory stores computer programs executable by the at least one processor. The processor 11 can perform various appropriate actions and processes based on the computer program stored in the ROM 12 or loaded from storage unit 18 into the RAM 13. The RAM 13 can also store various programs and data required for the operation of the electronic device 10. The processor 11, ROM 12, and RAM 13 are interconnected via a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0101] Multiple components in electronic device 10 are connected to I / O interface 15, including: input unit 16, such as keyboard, mouse, etc.; output unit 17, such as various types of displays, speakers, etc.; storage unit 18, such as disk, optical disk, etc.; and communication unit 19, such as network card, modem, wireless transceiver, etc. Communication unit 19 allows electronic device 10 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0102] Processor 11 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of processor 11 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 11 performs the various methods and processes described above, such as the deposition microphase determination method.

[0103] In some embodiments, the deposition microphase determination method may be implemented as a computer program tangibly contained in a computer-readable storage medium, such as storage unit 18. In some embodiments, part or all of the computer program may be loaded and / or mounted on electronic device 10 via ROM 12 and / or communication unit 19. When the computer program is loaded into RAM 13 and executed by processor 11, one or more steps of the deposition microphase determination method described above may be performed. Alternatively, in other embodiments, processor 11 may be configured to perform the deposition microphase determination method by any other suitable means (e.g., by means of firmware).

[0104] 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 computer 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 storage system, at least one input device, and at least one output device, and transmitting data and instructions to the storage system, the at least one input device, and the at least one output device.

[0105] Computer programs for implementing the depositional microphase determination method of the present invention can be written in any combination of one or more programming languages. These computer 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 computer programs cause the functions / operations specified in the flowcharts and / or block diagrams to be implemented. The computer 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.

[0106] Example 5

[0107] Embodiment 5 of the present invention also provides a computer-readable storage medium storing computer instructions for causing a processor to execute a method for determining depositional microphases, the method comprising:

[0108] The target formation range of the target well is determined, and the target section is determined based on the target formation range; the profile of the target section is analyzed and processed based on 3D seismic data to determine the seismic response characteristics of the target section, and the seismic horizon data of the target section is determined based on the seismic response characteristics; the paleogeomorphological reconstruction of the target section is performed based on the seismic horizon data to obtain the paleogeomorphological image of the target section during the depositional period; based on the heavy mineral analysis parameters and stratigraphic dip parameters of at least one existing well in the target area to which the target well belongs, and the paleogeomorphological image, the paleochannel planar distribution map of the target section is determined; based on the seismic horizon data and the paleochannel planar distribution map, the fine sedimentary microfacies map of the target section is determined.

[0109] In the context of this invention, a computer-readable storage medium can be a tangible medium that may contain or store a computer 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.

[0110] To provide interaction with a user, the systems and techniques described herein can be implemented on an electronic device having: 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 electronic device. Other types of devices can also be used to provide interaction with the user; 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).

[0111] 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.

[0112] A computing system can include clients and servers. Clients and servers are generally located far apart and typically interact through communication networks. The client-server relationship is created by computer 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.

[0113] 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.

[0114] 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 determining sedimentary microfacies, characterized in that, include: Determine the target formation range of the target well, and determine the target formation segment based on the target formation range; Based on the analysis and processing of the profile of the target layer using 3D seismic data, the seismic response characteristics of the target layer are determined, and the seismic horizon data of the target layer are determined based on the seismic response characteristics. Based on the seismic stratigraphic data, the paleogeomorphology of the target stratigraphic segment is restored to obtain a paleogeomorphological image of the target stratigraphic segment during the depositional period; Based on the heavy mineral analysis parameters and formation dip angle parameters of at least one drilled well in the target area to which the target well belongs, and the paleogeographic image, a paleochannel planar distribution map of the target layer is determined. Based on the seismic stratigraphic data and the paleochannel planar distribution map, a detailed sedimentary microfacies map of the target stratigraphic segment is determined.

2. The method according to claim 1, characterized in that, Determining the target formation range of the target well and determining the target formation segment based on the target formation range includes: The target well is divided based on a short-term cycle division method to obtain at least one range of selectable layer groups; The target layer range is determined based on the oil and gas properties within the range of at least one candidate layer group. Based on the short-term cycle division method, the target layer group range is divided to obtain at least one sand group to be selected. Based on the oil and gas properties of the at least one sand group to be selected, a target sand group is determined and the target sand group is designated as the target layer.

3. The method according to claim 1, characterized in that, The analysis and processing of the profile of the target layer based on 3D seismic data to determine the seismic response characteristics of the target layer includes: Based on the aforementioned three-dimensional seismic data, the profile of the target layer is finely labeled to obtain the seismic response characteristics; Accordingly, determining the seismic horizon data of the target segment based on the seismic response characteristics includes: Based on the seismic response characteristics, the fine horizons of the fine horizon calibration are analyzed to determine the seismic horizon data.

4. The method according to claim 1, characterized in that, The paleogeomorphological reconstruction process of the target segment based on the seismic stratigraphic data, to obtain a paleogeomorphological image of the target segment during the depositional period, includes: The seismic stratigraphic data is input into the geomorphological reconstruction model to determine the geomorphological information corresponding to the target stratigraphic segment during the depositional period, and a paleogeographic image of the target stratigraphic segment during the depositional period is generated based on the geomorphological information.

5. The method according to claim 1, characterized in that, Also includes: Determine the heavy mineral analysis parameters and formation dip angle parameters of at least one drilled well within the target area; Determining the heavy mineral analysis parameters and formation dip angle parameters of at least one drilled well within the target area includes: Obtain information on the heavy mineral composition of the at least one drilled well in the target formation; Based on the distribution of the heavy mineral composition information in the profile of the target layer, the provenance direction in the heavy mineral analysis parameters is determined; Based on the dip angle of the target stratigraphic segment, the depositional region and water flow direction in the stratigraphic dip angle parameters are determined.

6. The method according to claim 1, characterized in that, The step of determining the fine sedimentary microfacies map of the target section based on the seismic stratigraphic data and the paleochannel planar distribution map includes: Based on the seismic horizon data, the seismic inversion map and seismic sensitivity attribute prediction map of the target segment are determined; Based on the earthquake inversion map, the earthquake sensitivity attribute prediction map, and the paleochannel planar distribution map, the fine sedimentary microfacies map is determined.

7. A device for determining sedimentary microphases, characterized in that, include: The target layer segment determination module is used to determine the target layer group range of the target well and determine the target layer segment based on the target layer group range; The seismic horizon data determination module is used to analyze and process the profile of the target layer based on three-dimensional seismic data, determine the seismic response characteristics of the target layer, and determine the seismic horizon data of the target layer based on the seismic response characteristics. The paleogeographic image determination module is used to perform paleogeographic reconstruction processing on the target segment based on the seismic stratigraphic data to obtain the paleogeographic image of the target segment during the depositional period; The paleochannel plan distribution map determination module is used to determine the paleochannel plan distribution map of the target layer based on the heavy mineral analysis parameters and stratigraphic dip angle parameters of at least one drilled well in the target area to which the target well belongs, and the paleogeographic image. The sedimentary microfacies map determination module is used to determine the fine sedimentary microfacies map of the target section based on the seismic stratigraphic data and the paleochannel planar distribution map.

8. An electronic device, characterized in that, The electronic device includes: At least one processor; and A memory communicatively connected to the at least one processor; wherein, The memory stores a computer program that can be executed by the at least one processor to enable the at least one processor to perform the deposition microphase determination method according to any one of claims 1-6.

9. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that cause a processor to execute the depositional microphase determination method according to any one of claims 1-6.

10. A computer program product, comprising a computer program, characterized in that, When the computer program is executed by a processor, it implements the depositional microphase determination method as described in any one of claims 1-6.

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