Deposition configuration depicting method and device, storage medium, processor and program product

Abstract

The embodiment of the invention provides a deposition configuration depicting method and device, a storage medium, a processor and a program product, and belongs to the technical field of oil exploration and development. The method comprises the following steps: acquiring a sedimentary configuration mode in a target work area obtained based on logging data, lithology data and a seismic data volume; based on the lithology data and the logging data, determining low-frequency, intermediate-frequency and high-frequency single-frequency bodies of each sedimentary layer in the sedimentary configuration mode from the seismic data body, and obtaining an RGB frequency division attribute fusion image of the target work area; extracting a configuration boundary skeleton graph from the RGB frequency division attribute fusion graph by adopting a morphological method; and depicting boundary features of each of the plurality of configuration units in the target work area and contact features of different configuration units in the plurality of configuration units based on the extracted configuration boundary skeleton so as to complete deposition configuration depiction in the target work area. According to the method, the limitation of low-resolution seismic data can be overcome, and the description of the configuration unit in the exploration target work area, especially the description of the river channel configuration unit, is completed.

Description

Technical Field

[0001] This invention relates to the field of petroleum exploration and development technology, and specifically to a method, apparatus, storage medium, processor, and program product for characterizing sedimentary configurations. Background Technology

[0002] With the advancement of gas field production and development in offshore low-well areas, the detailed characterization of multi-level sand body structures has become crucial for oil and gas field development. However, the quality of deep-sea seismic data is relatively low, well spacing is large, large braided channels are superimposed in multiple phases, and the impedance differences between sandstone and mudstone are small, making it difficult to characterize structures at the single-channel level, which cannot meet the needs of oil field production and development. Therefore, accurate identification and detailed characterization of single channels are an important foundation for the efficient development of gas reservoirs in offshore low-well areas. Summary of the Invention

[0003] The purpose of this invention is to provide a method for characterizing sedimentary configurations, which can overcome the limitations of low-resolution seismic data and characterize configuration units, especially channel configuration units, within the exploration target area.

[0004] To achieve the above objectives, embodiments of the present invention provide a method for characterizing depositional configurations, comprising:

[0005] Obtain sedimentary configuration patterns within the target work area based on well logging data, lithological data, and seismic data volumes;

[0006] Based on lithological and well logging data, the low-frequency, mid-frequency, and high-frequency single-frequency volumes of each sedimentary layer in the sedimentary configuration model are determined from the seismic data volume, and the RGB frequency-division attribute fusion map of the target work area is obtained.

[0007] Morphological methods were used to extract the configuration boundary skeleton map from the RGB frequency division attribute fusion map; and

[0008] Based on the extracted configuration boundary skeleton, the boundary features of each of the multiple configuration units in the target work area and the contact features of different configuration units in the multiple configuration units are characterized to complete the characterization of the deposition configuration in the target work area.

[0009] Optionally, the depositional configuration modes include: multiple configuration units and the vertical stacking and lateral splicing relationships between multiple configuration units.

[0010] Optionally, the multiple configuration units include at least one single channel configuration unit and / or at least one barbar configuration unit.

[0011] Optionally, the multiple configuration units may also include composite configuration units, which may include one or more single channel configuration units and / or one or more bar configuration units.

[0012] Preferably, the sedimentary configuration model within the target work area is obtained based on well logging data, lithological data, and seismic data volumes, including:

[0013] Obtain geological background data for the target work area, including a preliminary stratigraphic framework;

[0014] By combining the stratigraphic characteristics reflected in well logging data, lithological data, and seismic data volumes, the stratigraphic framework is refined.

[0015] Establish a configuration interface system reflecting the sedimentary characteristics of the target work area, and define the order and type of configuration units in the stratigraphic framework based on well-seismic calibration results; and

[0016] Determine the vertical stacking and lateral splicing relationships between the defined configuration units, and establish a depositional configuration model.

[0017] Furthermore, by combining the stratigraphic characteristics reflected in well logging data, lithological data, and seismic data volumes, the stratigraphic framework is refined, including:

[0018] Based on well logging and lithological data, the lithological and electrical characteristics, sedimentary cycles, and stratigraphic markers of the target sedimentary layer within the preliminarily established stratigraphic framework were determined, and the target sedimentary layer was further subdivided into smaller layers; and

[0019] For the subdivided sedimentary layers, seismic horizon interpretation is performed in conjunction with seismic data volumes to obtain the top and bottom time-domain stratigraphic interfaces of each sedimentary layer, so as to obtain a stratigraphic framework that meets the accuracy requirements.

[0020] Furthermore, a configuration interface system reflecting the sedimentary characteristics of the target work area is established, and the hierarchy and type of configuration units in the stratigraphic framework are defined in conjunction with well-seismic calibration results, including:

[0021] Based on the existing patterns of morphological interfaces and sedimentary structures, and combined with geological background data, seismic data, and sedimentary characteristics reflected in well logging data, a morphological interface system for the target work area is established and delineated.

[0022] By combining the well-seismic calibration results of seismic data volumes and well logging data, the profiles and configuration interface systems of the seismic data volumes are interpreted to determine the order and type of configuration units contained in the target sedimentary layer.

[0023] Furthermore, the vertical stacking and lateral splicing relationships between the defined configuration units are determined, and a sedimentary configuration model is established, including:

[0024] By combining the characteristics of well logging curves in the well logging data and the lithological identification results in the lithological data, the vertical boundaries of a single channel configuration unit and / or a core bar configuration unit are calibrated in the configuration interface system.

[0025] Combining seismic phase axis amplitudes in the seismic data volume with lithological variations in the lithological data, the lateral boundaries of single channel configuration units and / or bar / shoal configuration units are calibrated in the configuration interface system; and

[0026] Based on the calibration results of the configuration interface system, combined with the reflection characteristics of seismic profiles and the comparison rules of well profiles, the vertical stacking and lateral splicing relationships between different configuration units are determined and a sedimentary configuration model is established.

[0027] Preferably, based on lithological data and well logging data, low-frequency, mid-frequency, and high-frequency volumes of each sedimentary layer in the sedimentary configuration model are determined from the seismic data volume to obtain the RGB frequency-separated attribute fusion map of the target work area, including:

[0028] For each sedimentary layer, the seismic data volume is sliced, and based on the tuning effect and the principle of interlayer interference, low-frequency, mid-frequency, and high-frequency single-frequency volumes that conform to the distribution characteristics of sand bodies of different thicknesses are selected and determined.

[0029] Wavelet transform is used to fuse low-frequency, mid-frequency, and high-frequency single-frequency volumes, and different scales and frequency bands are varied to obtain an RGB frequency-division attribute fusion map that meets the requirements of planar resolution and color resolution.

[0030] Preferably, a morphological method is used to extract the configuration boundary skeleton map from the RGB frequency division attribute fusion map, including:

[0031] The RGB frequency division attribute fusion map was processed using a morphological gradient algorithm to obtain the initial gradient boundary of the sand body, and the obtained gradient boundary of the sand body was then thresholded.

[0032] Multiple iterative erosion operations are performed along the direction perpendicular to the gradient, as shown in the following formula, to refine the boundary skeleton from the initially obtained sand body gradient boundary, thus obtaining the configuration boundary skeleton diagram:

[0033]

[0034] In the formula, SEdge represents the sand body boundary skeleton; A represents the sand body gradient boundary; B represents the structuring element; Θ is the erosion operator; K represents the number of iterations of the erosion operation; and θ represents the direction of the gradient vector at the boundary points on the sand body gradient boundary. It is an empty set.

[0035] Preferably, the boundary features of each of the multiple configuration units within the target work area and the contact features of different configuration units within the multiple configuration units are characterized based on the extracted configuration boundary skeleton, including:

[0036] Based on the distribution characteristics of mudstone and sandstone reflected by the light and dark differences in the RGB attribute fusion map, a hierarchical analysis of the sedimentary configuration model is performed to determine the interface of the composite configuration unit in multiple configuration units. The composite configuration unit includes a composite channel interface or a single braided zone interface.

[0037] The boundaries of single channel configuration units and / or bar-type configuration units are determined under the constraints of the interfaces of composite configuration units, and are used to describe the boundary characteristics of the corresponding configuration units.

[0038] By combining the chromaticity differences reflected in the RGB attribute fusion diagram to indicate sand body thickness distribution characteristics and the mudstone distribution characteristics reflected in the configuration boundary framework diagram, sedimentary configuration models are analyzed to determine the interfaces of single channel configuration units and / or mid-channel bar configuration units, which are then used to describe the boundary characteristics of the corresponding configuration units; and

[0039] Analyze the contact relationships between the same or different types of configuration units, and use them to describe the contact characteristics between the corresponding configuration units.

[0040] On the other hand, embodiments of the present invention provide a deposition configuration characterization apparatus, comprising:

[0041] The sedimentary configuration pattern determination module acquires the sedimentary configuration patterns within the target work area based on well logging data, lithological data, and seismic data volumes.

[0042] The configuration characterization determination module, based on lithological data and well logging data, determines the low-frequency, mid-frequency, and high-frequency single-frequency volumes of each sedimentary layer in the sedimentary configuration model from the seismic data volume, and obtains the RGB frequency-division attribute fusion map of the target work area.

[0043] The configuration boundary extraction module uses morphological methods to extract the configuration boundary skeleton map from the RGB frequency division attribute fusion map; and

[0044] The configuration feature characterization module characterizes the boundary features of each of the multiple configuration units in the target work area and the contact features of different configuration units in the multiple configuration units based on the extracted configuration boundary skeleton, so as to complete the deposition configuration characterization in the target work area.

[0045] On the other hand, embodiments of the present invention provide a processor configured to execute the deposition configuration characterization method of the present application.

[0046] On the other hand, embodiments of the present invention provide an electronic device, including: a processor, and a memory communicatively connected to the processor;

[0047] The memory stores the instructions that the computer executes;

[0048] The processor executes computer execution instructions stored in memory to implement the deposition configuration characterization method of this application.

[0049] On the other hand, embodiments of the present invention provide a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, are used to implement the deposition configuration characterization method of the present application.

[0050] On the other hand, embodiments of the present invention provide a computer program product, including a computer program that, when executed by a processor, implements the deposition configuration characterization method of the present application.

[0051] The above technical solution first identifies and fuses low-frequency, mid-frequency, and high-frequency single-frequency volumes that conform to the characteristics of each sedimentary layer in the sedimentary configuration model from the seismic data volume based on lithological and well logging data. Then, morphological methods are used to extract the configuration boundary skeleton map from the fused map. Finally, based on the extracted configuration boundary skeleton, the boundary features of each of the multiple configuration units in the target area and the contact features of different configuration units in multiple configuration units are characterized to complete the sedimentary configuration characterization in the target area. When the quality of seismic data is low, lithological and well logging data are introduced to guide the slicing and interpretation of the seismic data volume, thereby extracting the configuration boundary skeleton map and the boundary features and contact features between configurations, including vertical overlay and lateral contact features, thus completing the fine characterization of the sedimentary configuration.

[0052] Other features and advantages of the embodiments of the present invention will be described in detail in the following detailed description section. Attached Figure Description

[0053] The accompanying drawings are provided to further illustrate embodiments of the present invention and form part of the specification. They are used together with the following detailed description to explain the embodiments of the present invention, but do not constitute a limitation thereof. In the drawings:

[0054] Figure 1 This is a flowchart of an embodiment of the deposition configuration characterization method of the present invention;

[0055] Figure 2 This is a flowchart of another embodiment of the deposition configuration characterization method of the present invention;

[0056] Figure 3 for Figure 2 The example uses a high-precision stratigraphic grid map obtained from well-to-well correlation.

[0057] Figure 4 for Figure 2 A schematic diagram of the target work area configuration interface identification and division obtained in the embodiment;

[0058] Figure 5 for Figure 2 A diagram showing the stacking pattern of the configuration units of the target work area obtained in the embodiment;

[0059] Figure 6 for Figure 5 The well seismic response characteristics of the stacked configuration units shown are illustrated.

[0060] Figure 7 for Figure 2 The RGB attribute fusion diagrams with 17Hz, 22Hz and 27Hz frequency division obtained in the embodiment;

[0061] Figure 8 for Figure 2 The cross-plot of the well logging interpretation sand body thickness and the RGB response sand body thickness obtained in the example;

[0062] Figure 9 for Figure 2 The configuration boundary skeleton diagram extracted in the embodiment;

[0063] Figure 10 for Figure 2 Plan view of the single channel configuration unit and the mid-shoal bar configuration unit obtained in the embodiments; and

[0064] Figure 11 This is a structural diagram of an embodiment of the deposition configuration characterization apparatus of the present invention. Detailed Implementation

[0065] The specific embodiments of the present invention will be described in detail below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are for illustration and explanation only and are not intended to limit the scope of the present invention.

[0066] To make the objectives, technical solutions, and advantages of the embodiments of this application clearer, the technical solutions of the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are only for illustration and explanation of the embodiments of this application and are not intended to limit the embodiments of this application. All other embodiments obtained by those skilled in the art based on the embodiments of this application without creative effort are within the scope of protection of this application.

[0067] The acquisition, transmission, storage, use, and processing of data in this application comply with relevant national laws and regulations. It should be noted that certain software, components, models, and other existing industry solutions may be mentioned in the embodiments of this application. These should be considered exemplary, intended only to illustrate the feasibility of implementing the technical solution of this application, and do not imply that the applicant has already used or necessarily used such solutions.

[0068] This invention provides a method for characterizing depositional configurations, which can be used to characterize the boundary features of each of multiple configurational units within a target work area and the contact features of different configurational units within the multiple configurational units, thereby describing the overall depositional situation of the target work area. The implementation process is as follows: Figure 1 As shown, it includes the following steps:

[0069] Step S10: Obtain the sedimentary configuration pattern within the target work area based on well logging data, lithological data, and seismic data.

[0070] Step S20: Based on lithological data and well logging data, determine the low-frequency single-frequency volume, mid-frequency single-frequency volume and high-frequency single-frequency volume of each sedimentary layer in the sedimentary configuration model from the seismic data volume, and obtain the RGB frequency-division attribute fusion map of the target work area;

[0071] Step S30: Extract the configuration boundary skeleton map from the RGB frequency division attribute fusion map using morphological methods;

[0072] Step S40: Based on the extracted configuration boundary skeleton, characterize the boundary features of each of the multiple configuration units in the target work area and the contact features of different configuration units in the multiple configuration units, so as to complete the characterization of the deposition configuration in the target work area.

[0073] In this embodiment, step S20 identifies and fuses low-frequency, mid-frequency, and high-frequency single-frequency volumes that conform to the characteristics of each sedimentary layer in the sedimentary configuration model from the seismic data volume, obtaining an RGB frequency-division attribute fusion map based on lithological data and well logging data. This compensates for the deficiencies of low-resolution seismic data. Then, in step S30, a morphological method is used to extract the configuration boundary skeleton map from the RGB frequency-division attribute fusion map, identifying multiple configuration units in the target work area. Finally, in step S40, based on the extracted configuration boundary skeleton, the boundary features of each of the multiple configuration units in the target work area and the contact features of different configuration units are depicted, thereby describing the boundary features of each configuration unit and the contact features between different configuration units. The contact features between different configuration units can be used to describe the vertical stacking and lateral splicing relationships between configuration units of the same or different levels.

[0074] It should be noted that, in this embodiment, based on existing knowledge of configuration interface systems and sedimentary structures, and combined with the sedimentary characteristics reflected by geological, well logging, and seismic data within the work area, the following eight levels of configuration interfaces were identified within the work area:

[0075] Level 8: Unconformity, corresponding to the Huagang Movement and Yuquan Movement at the top and bottom of the Huagang Formation.

[0076] Level 7: Maximum lacustrine flooding surface, which, based on previous data, should correspond to the bottom of the 6th member of the Huagang Formation. The unit it defines is a large sedimentary system, which did not appear in the data of this study area.

[0077] Level 6: Defines the boundary of the paleochannel group, corresponding to the top and bottom of H3. It mainly consists of widely distributed mudstone, exhibiting high gamma and low potential characteristics in well logging curves.

[0078] Level 5: Braided channel interfaces, which are the main erosion or floodplain surfaces. This includes the boundaries of single braided channel zones formed by the vertical and lateral superposition of multiple braided channels, such as the top and bottom of H3b-2 and H3b-3, as well as the interfaces of composite channels formed by the vertical superposition of multiple single braided channel zones, such as the top and bottom of the H3a and H3b sandstone groups. The interfaces are mostly composed of fine-grained sediments such as mudstone or fine sandstone, and the well logging curves exhibit high gamma and low potential characteristics. There are significant differences in lithofacies assemblages above and below the interfaces.

[0079] Level 4: Large-scale interface with a single core bar top and bottom mudstone interface or a single underwater distributary channel bottom scour, corresponding to sedimentary microfacies. The limiting morphological unit is a core bar or an underwater distributary channel. The core bar is "flat bottom and convex top" while the underwater distributary channel is "flat top and convex bottom". Laterally, the two are often spliced ​​together in the form of "distributary channel - core bar - distributary channel" and "core bar - distributary channel - core bar".

[0080] Level 3: Accretionary bodies within large bottom formations, i.e., muddy strata and accretionary bodies within a single underwater distributary channel or mid-bar, thinner than the mudstone at the Level 4 interface, with similar lithofacies assemblages above and below the interface. Due to data resolution limitations, they are difficult to identify in this work area.

[0081] Level 2: Simple stratigraphic interface. There are changes in lithofacies above and below the interface (the difference from the Level 1 interface).

[0082] Level 1: Interface of cross-strata. There is little or no erosion on the interface; the interface is not obvious on the core and can be identified by the erosion or pinch-out of the pre-cross-strata.

[0083] Grade 0: Laminar interface, not obvious on the core, and difficult to identify.

[0084] Furthermore, in this embodiment, the single channel and the mid-shoal dam in the 4th-level configuration interface are taken as the key research objects. Combined with the well-seismic joint results, the characteristics of the 4th-level configuration unit are described and identified.

[0085] Compared with the prior art, the technical advantages of this embodiment are as follows:

[0086] When the resolution of seismic data is insufficient, RGB frequency-division attribute fusion maps that conform to the characteristics of each sedimentary layer in the sedimentary configuration model are determined based on the seismic data volume and combined with lithological data and well logging data. Then, configuration boundary skeleton maps are extracted from the RGB frequency-division attribute fusion maps to identify the boundary features of multiple configuration units in the target work area and the contact features between the same or different types of configuration units in multiple configuration units. This enables a detailed description of the boundary, vertical stacking and lateral splicing relationships between configuration units of the same or different levels in the target sedimentary layer.

[0087] In some implementations, the configuration within the work area is complex. The deposition configuration pattern within the target work area obtained in step 20 includes: multiple configuration units and the vertical stacking and lateral splicing relationships between multiple configuration units.

[0088] In some implementations, the plurality of configuration units also include at least one single channel configuration unit and / or at least one barbar configuration unit.

[0089] In some embodiments, the plurality of configuration units also include composite configuration units, which include one or more single channel configuration units and / or one or more bar-dam configuration units.

[0090] exist Figure 1 Based on the embodiments shown, this application also proposes another preferred embodiment, combined with... Figure 2 The specific implementation steps of this embodiment are as follows.

[0091] In this embodiment, Figure 1 Step S10 of the embodiment is further subdivided into the following steps:

[0092] Step S11: Obtain geological background data for the target work area, including the preliminary stratigraphic framework.

[0093] Step S12: Combine well logging data, lithological data, and seismic data to refine the stratigraphic framework.

[0094] Step S13: Establish a configuration interface system that reflects the sedimentary characteristics of the target work area, and define the order and type of configuration units in the stratigraphic framework in combination with well-seismic calibration results;

[0095] Step S14: Determine the vertical stacking and lateral splicing relationships between the defined configuration units, and establish the deposition configuration pattern.

[0096] The high-precision stratigraphic framework diagram obtained from steps S11 and S12 above is as follows: Figure 3 As shown, the configuration interface reflecting the sedimentary characteristics of the target work area, identified and delineated in step S13, is as follows: Figure 4As shown, the stacking pattern diagram of the configuration unit obtained in step S14 is as follows: Figure 5 As shown, and the well seismic response characteristics based on the configuration unit stacking pattern are as follows: Figure 6 As shown.

[0097] In some implementations, step S12 above is further subdivided into:

[0098] Step S121: Based on well logging data and lithological data, determine the lithological and electrical characteristics, sedimentary cycles, and stratigraphic markers of the target sedimentary layer in the initially established stratigraphic framework, and subdivide the target sedimentary layer into smaller layers;

[0099] Step S122: For the subdivided sedimentary layers, seismic horizon interpretation is performed in conjunction with the seismic data volume to obtain the top and bottom time domain stratigraphic interfaces of each sedimentary layer, so as to obtain a stratigraphic framework that meets the accuracy requirements.

[0100] It should be noted that, Figure 3 The diagram also shows a comparison between the formation framework and well logging curves, used to illustrate how steps S121-S122 combine the formation characteristics reflected by the well logging curves to refine the formation framework. First, the main marker layer I, with its significant changes in well logging curves and clear distinctions in lithology and upper and lower layers, is selected to constrain the top and bottom of the target layer, the Huagang Formation, Member 3, and is used as the main marker layer to define H3. Main marker layer II is selected as the top of H3b, showing high gamma, low potential, and high neutrons in well logging, while cuttings logging indicates silty mudstone; this is also used as the main marker layer to define H3b. Auxiliary marker layer III is selected as the top of H3b-3, showing high gamma, low potential, and high neutrons in well logging, while cuttings logging indicates mudstone. Following the principles of isochronous control and hierarchical constraints, stratigraphic division of standard wells in the target work area was completed using primary and secondary marker layers; a skeleton profile was established, and sub-layer division and comparison of all wells in the work area were completed on the interconnected wells; the stratigraphic division results from well logging were imported into the seismic profile, and the seismic profile of the main producing layer was calibrated on the skeleton profile to obtain the response characteristics of the top and bottom interfaces of H3b-3 on the seismic profile; based on the seismic calibration results, the top and bottom of the H3b-3 sub-layer were interpreted to obtain the time domain stratigraphic interface of the target stratum H3b-3.

[0101] In some implementations, step S13 above is further subdivided into:

[0102] Step S131: Based on the existing structural interfaces and sedimentary structures, and combined with geological background data, seismic data, and sedimentary characteristics reflected by well logging data, establish and delineate the structural interface system of the target work area.

[0103] Step S132: Combining the well-seismic calibration results of the seismic data volume and well logging data, interpret the profile and configuration interface system of the seismic data volume to determine the order and type of configuration units contained in the target sedimentary layer.

[0104] Based on steps S131-S132 above, and combining the characteristics of the high-precision stratigraphic framework and braided river delta sedimentary units, morphological units are divided and morphological interfaces are identified, resulting in the characterization levels of single channels. Specifically, based on the seismic data of the target layer on the corresponding seismic profile, five levels of composite channel interfaces and single braided flow zone interfaces can be distinguished; on the plane, the seismic data of the target layer can detect four levels of morphological interfaces, including single channels and mid-channel bar boundaries. From... Figure 5 and Figure 6 Both show the identified distributary interfaces and the boundaries of the mid-channel dam.

[0105] In some implementations, step S14 above is further subdivided into:

[0106] Step S141: Combining the characteristics of well logging curves in the well logging data and the lithological identification results in the lithological data, the vertical boundaries of a single channel configuration unit and / or a bar configuration unit are calibrated in the configuration interface system.

[0107] Step S142: Combine the seismic phase axis amplitude in the seismic data volume and the sand content variation in the lithological data to define the lateral boundaries of the single channel configuration unit and / or the core bar configuration unit in the configuration interface system.

[0108] Step S143: Based on the calibration results of the configuration interface system, combined with the reflection characteristics of the seismic profile and the comparison law of the well profile, determine the vertical stacking and lateral splicing relationship between different configuration units and establish the sedimentary configuration model.

[0109] Specifically, in steps S141-S143 above, based on the results of sedimentary microfacies studies and combined with the seismic wave characteristics of the seismic profile, mid-channel bars often appear as strong wave peaks on the seismic profile, while distributary channels between mid-channel bars correspond to relatively weaker wave peaks. When the seismic wave amplitude is very weak, it corresponds to fine-grained sediments such as mudstone or siltstone in the interdistributary bay. The main layer H3b-3 has numerous mid-channel bars developed within the work area; therefore, the vertical morphological units of the main layer are mainly composed of vertical superpositions of mid-channel bars and distributary channels with mid-channel bars.

[0110] ①Xintanba-Xintanba Vertical Stacking Mode

[0111] The mid-channel bars developed in the main layer H3b-3 are often stacked vertically, and because the sub-layers belong to different single braided channel zones, the mid-channel bars formed belong to different channel series, with thin layers of fine-grained sediments as interlayers between them.

[0112] ② Vertical stacking pattern of Xintan Dam-Diversion Channel

[0113] Based on the changes in seismic wave characteristics on the seismic profile, the mid-channel bar often corresponds to the strong amplitude part of the seismic phase axis, indicating the development of thick sandstone. The seismic phase axis corresponding to the distributary channel corresponds to the relatively weak amplitude phase axis. Based on this, the vertical superposition pattern of the mid-channel bar and the distributary channel can be identified. In this pattern, the mid-channel bar and the distributary channel are still separate and not connected to each other.

[0114] ① Lateral splicing mode of Xintan Dam-River Channel-Xintan Dam

[0115] The main layer, especially the H3b-3 sublayer, has a large number of core bars. Small distributary channels often develop between different core bars. The core bar-channel-core bar pattern is the most common lateral splicing pattern in the work area. By combining well and seismic calibration, observing the changes in the amplitude and morphology of seismic waves on the seismic profile, and comparing them with the areas where the sandstone thickness thins on the plane, the boundaries of the core bars at the fourth-order configuration interface can be more accurately determined on the plane.

[0116] ② River channel – Xintan Dam – River channel lateral splicing mode

[0117] The channel-shoal-channel pattern is also a major lateral splicing pattern in the work area. Through well-seismic joint calibration, the seismic profile shows a change in the amplitude of the in-phase axis from weak to strong to weak. The places where the amplitude changes indicate the boundary between the channel and the channel, which can be used to further characterize the distribution of the fourth-order configuration interface on the plane.

[0118] The conclusions regarding the vertical stacking and lateral splicing modes can be found in [reference needed]. Figure 5 A schematic diagram of the stacking pattern of the configuration units.

[0119] In this embodiment, Figure 1 Step S20 of the embodiment is further subdivided into the following steps:

[0120] Preferably, based on lithological data and well logging data, low-frequency, mid-frequency, and high-frequency volumes of each sedimentary layer in the sedimentary configuration model are determined from the seismic data volume to obtain the RGB frequency-separated attribute fusion map of the target work area, including:

[0121] Step S21: For each sedimentary layer, the seismic data volume is sliced, and based on the tuning effect and interlayer interference principle, low-frequency single-frequency volume, mid-frequency single-frequency volume and high-frequency single-frequency volume that conform to the distribution characteristics of sand bodies of different thicknesses are selected and determined.

[0122] Step S22: Wavelet transform is used to fuse low-frequency single-frequency volume, mid-frequency single-frequency volume and high-frequency single-frequency volume, and different scales and frequency bands are changed to obtain an RGB frequency division attribute fusion map that meets the requirements of planar resolution and color resolution.

[0123] In this embodiment, based on the original parameters of the seismic data volume, the dominant frequency of the seismic data is determined to be approximately 27Hz, and the average velocity of the target layer is approximately 4200m / s. The wavelength is calculated based on the frequency (f) and wave velocity (v) of the seismic data volume, and the seismic tuning thickness is calculated; where λ = v / f, and the seismic tuning thickness ΔZ = λ / 4. The thickness of a single sand body is statistically analyzed, and suitable low-frequency, mid-frequency, and high-frequency single-frequency volumes are selected based on the sand body thickness distribution characteristics. Spectrum values ​​of 17Hz, 22Hz, and 27Hz are selected as the frequency-division volumes for fusion slicing. Different types of wavelet frequency division are tried, and the fusion results of different frequency division methods are compared. The optimal frequency division method is selected based on planar resolution and color resolution. Using wavelet transform, different resolutions can be given in different frequency bands according to scale changes and offsets, improving the characterization of configuration boundaries. An RGB frequency-division attribute fusion map obtained in this embodiment is shown below. Figure 7 As shown, the difference in light and dark areas reflects the characteristics of sand bodies or mud bodies at corresponding locations. Combining this characteristic with hierarchical analysis of sedimentary configuration patterns can identify the boundaries of higher-order configuration units. Figure 7 Further results were obtained on this basis. Figure 8 The diagram shown is a cross-plot of the well logging interpretation sand body thickness and the RGB response sand body thickness.

[0124] In this embodiment, Figure 1 Step S30 of the embodiment is further subdivided into the following steps:

[0125] Step S31: The RGB frequency division attribute fusion map is processed using the morphological gradient algorithm to initially obtain the sand body gradient boundary, and the obtained sand body gradient boundary is thresholded.

[0126] Step S32: Perform multiple iterations of erosion operations along the direction perpendicular to the gradient, as shown in the following formula, to refine the boundary skeleton from the initially obtained sand body gradient boundary, thus obtaining the configuration boundary skeleton diagram:

[0127]

[0128] In the formula, SEdge represents the sand body boundary skeleton; A represents the sand body gradient boundary; B represents the structuring element; Θ is the erosion operator; K represents the number of iterations of the erosion operation; and θ represents the direction of the gradient vector at the boundary points on the sand body gradient boundary. It is an empty set.

[0129] It should be noted that the aforementioned structuring element refers to the structuring element of a rectangle, ellipse, or other shape selected for computation in morphological algorithms.

[0130] The configuration boundary skeleton obtained in this embodiment is as follows: Figure 9 As shown, it is used to reflect the distribution characteristics of mudstone. Therefore, by combining it with the configuration boundary skeleton diagram, the configuration unit can be further refined.

[0131] In this embodiment, Figure 1 Step S40 of the embodiment is further subdivided into the following steps:

[0132] Step S41: Combine the light and dark differences in the RGB attribute fusion diagram to perform hierarchical analysis on the sedimentary configuration mode and determine the interface of the composite configuration unit in multiple configuration units. The composite configuration unit includes a composite channel interface or a single braided zone interface.

[0133] Step S42: Determine the boundaries of single channel configuration units and / or mid-shoal bar configuration units under the constraints of the interfaces of composite configuration units, and use them to describe the boundary characteristics of the corresponding configuration units.

[0134] Step S43: Combine the color differences in the RGB attribute fusion diagram, the characteristics of sand body thickness distribution, and the configuration boundary skeleton diagram to analyze the sedimentary configuration pattern, determine the interface of a single channel configuration unit and / or a mid-channel bar configuration unit, and use it to describe the boundary characteristics of the corresponding configuration unit.

[0135] Step S44: Analyze the contact relationships between the same or different types of configuration units, and use them to describe the contact characteristics between the corresponding configuration units.

[0136] In this embodiment, a hierarchical analysis, facies mode guidance, and configuration splicing style are comprehensively applied. Based on the extracted configuration boundary skeleton in the RGB frequency division attribute fusion map, the boundaries of level 4 and 5 configuration units are identified, completing the detailed characterization of single channels. Guided by the braided river delta depositional model, hierarchical analysis is used to first determine the level 5 composite channel interface or single braided zone interface. Under the constraint of the level 5 interface, the level 4 single channel boundary is clarified. Guided by the configuration style, the level 4 single channel / spiking bar interface is identified by combining the RGB attribute fusion map, configuration boundary skeleton map, and sand body thickness variation characteristics. The planar distribution of the identified single channel configuration units and piping bar configuration units is shown below. Figure 10 As shown.

[0137] This invention provides a deposition configuration characterization apparatus, such as... Figure 11 As shown, it includes a sedimentary configuration pattern determination module, a configuration characterization determination module, a configuration characterization determination module, and a configuration feature characterization module, wherein,

[0138] The sedimentary configuration pattern determination module acquires the sedimentary configuration patterns within the target work area based on well logging data, lithological data, and seismic data volumes.

[0139] The configuration characterization determination module, based on lithological data and well logging data, determines the low-frequency, mid-frequency, and high-frequency single-frequency volumes of each sedimentary layer in the sedimentary configuration model from the seismic data volume, and obtains the RGB frequency-division attribute fusion map of the target work area.

[0140] The configuration boundary extraction module uses morphological methods to extract the configuration boundary skeleton map from the RGB frequency division attribute fusion map; and

[0141] The configuration feature characterization module characterizes the boundary features of each of the multiple configuration units in the target work area and the contact features of different configuration units in the multiple configuration units based on the extracted configuration boundary skeleton, so as to complete the deposition configuration characterization in the target work area.

[0142] This invention provides a deposition configuration characterization apparatus, including a processor and a memory. The aforementioned deposition configuration pattern determination module, configuration characterization determination module, configuration characterization determination module, and configuration feature characterization module are all stored as program units in the memory, and the processor executes the aforementioned program units stored in the memory to realize the corresponding functions.

[0143] The processor contains a core, which retrieves the corresponding program unit from memory. One or more cores can be configured, and the fine characterization of the deposition configuration can be achieved by adjusting the core parameters.

[0144] The memory may include non-permanent memory in computer-readable media, such as random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash RAM, and the memory includes at least one memory chip.

[0145] This invention provides a storage medium storing a program that, when executed by a processor, implements the deposition configuration characterization method of this application.

[0146] This invention provides a processor for running a program, wherein the program executes the deposition configuration characterization method of this application during runtime.

[0147] This application provides an electronic device, which includes a processor, a memory, and a program stored in the memory and executable on the processor. When the processor executes the program, it implements the steps of the deposition configuration characterization method of this application.

[0148] This application also provides a computer program product that, when executed on a data processing device, is adapted to execute a program that initializes the deposition configuration characterization method steps of this application.

[0149] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0150] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart... Figure 1 a process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0151] These computer program instructions may also be stored in a computer readable memory that can direct a computer or other programmable data processing device to work in a specific manner, so that the instructions stored in the computer readable memory produce an article of manufacture comprising an instruction device, which implements the process Figure 1 a process or multiple processes and / or boxes Figure 1 The function specified in one or more boxes.

[0152] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operational steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing the instructions executed on the computer or other programmable device for implementing the process. Figure 1 a process or multiple processes and / or boxes Figure 1 A step that specifies a function in one or more boxes.

[0153] In a typical configuration, a computing device includes one or more processors (CPU), input / output interfaces, network interfaces, and memory.

[0154] Memory may include non-persistent memory in computer-readable media, such as random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash RAM. Memory is an example of computer-readable media.

[0155] Computer-readable media includes permanent and non-permanent, removable and non-removable media that can be implemented by any method or technology to store information. The information can be computer-readable instructions, data structures, program modules or other data. Examples of computer storage media include, but are not limited to, phase change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technology, compact disc read-only memory (CD-ROM), digital versatile disc (DVD) or other optical storage, magnetic cassettes, magnetic tape, magnetic disk storage or other magnetic storage devices or any other non-transmission media that can be used to store information that can be accessed by a computing device. As defined herein, computer-readable media does not include transitory computer-readable media (transitory media), such as modulated data signals and carrier waves.

[0156] It should also be noted that the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such process, method, article, or apparatus. Unless otherwise specified, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes that element.

[0157] The above are merely embodiments of this application and are not intended to limit the scope of this application. Various modifications and variations can be made to this application by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this application should be included within the scope of the claims of this application.

Claims

1. A method for characterizing sedimentary configurations, comprising: Obtain sedimentary configuration patterns within the target work area based on well logging data, lithological data, and seismic data volumes; Based on the lithological data and the well logging data, the low-frequency single-frequency volume, mid-frequency single-frequency volume and high-frequency single-frequency volume of each sedimentary layer in the sedimentary configuration model are determined from the seismic data volume to obtain the RGB frequency-division attribute fusion map of the target work area; The configuration boundary skeleton map is extracted from the RGB frequency division attribute fusion map using morphological methods; and Based on the extracted configuration boundary skeleton, the boundary features of each of the multiple configuration units in the target work area and the contact features of different configuration units in the multiple configuration units are characterized to complete the deposition configuration characterization in the target work area.

2. The depositional configuration characterization method according to claim 1, characterized in that, The depositional configuration includes: multiple configuration units and the vertical stacking and lateral splicing relationships between the multiple configuration units.

3. The depositional configuration characterization method according to claim 1, characterized in that, The plurality of configuration units include at least one single channel configuration unit and / or at least one mid-shoal dam configuration unit.

4. The depositional configuration characterization method according to claim 1, characterized in that, The plurality of configuration units also include composite configuration units, which include one or more single channel configuration units and / or one or more channel dam configuration units.

5. The depositional configuration characterization method according to claim 1, characterized in that, The acquisition of sedimentary configuration patterns within the target work area based on well logging data, lithological data, and seismic data volumes includes: Obtain geological background data for the target work area, including a preliminary stratigraphic framework; The stratigraphic framework is refined by combining the stratigraphic characteristics reflected in the well logging data, lithological data, and seismic data. Establish a configuration interface system reflecting the sedimentary characteristics of the target work area, and define the order and type of configuration units in the stratigraphic framework based on well-seismic calibration results; and Determine the vertical stacking and lateral splicing relationships between the defined configuration units, and establish the deposition configuration pattern.

6. The depositional configuration characterization method according to claim 5, characterized in that, The refinement of the stratigraphic framework, based on the stratigraphic characteristics reflected by the well logging data, lithological data, and seismic data, includes: Based on the well logging data and lithological data, the lithological and electrical characteristics, sedimentary cycles, and stratigraphic markers of the target sedimentary layer within the preliminarily established stratigraphic framework are determined, and the target sedimentary layer is subdivided into smaller layers; and For the subdivided sedimentary layers, seismic stratigraphic interpretation is performed in conjunction with the seismic data volume to obtain the top and bottom time-domain stratigraphic interfaces of each sedimentary layer, so as to obtain a stratigraphic framework that meets the accuracy requirements.

7. The depositional configuration characterization method according to claim 5, characterized in that, The establishment of a configuration interface system reflecting the sedimentary characteristics of the target work area, and the determination of the hierarchy and type of configuration units in the stratigraphic framework based on well-seismic calibration results, includes: Based on the existing patterns of morphological interfaces and sedimentary structures, and combined with the geological background data, the seismic data, and the sedimentary characteristics reflected in the well logging data, a morphological interface system for the target work area is established and delineated. By combining the well-seismic calibration results of the seismic data volume and the well logging data, the profile of the seismic data volume and the configuration interface system are interpreted to determine the order and type of the configuration units contained in the target sedimentary layer.

8. The depositional configuration characterization method according to claim 7, characterized in that, The process of determining the vertical stacking and lateral splicing relationships between the defined configuration units and establishing the depositional configuration pattern includes: Combining the logging curve characteristics in the logging data and the lithology identification results in the lithology data, the vertical boundaries of the single channel configuration unit and / or the core bar configuration unit are calibrated in the configuration interface system; Combining the seismic phase axis amplitudes in the seismic data volume and the lithological variations in the lithological data, the lateral boundaries of the single channel configuration unit and / or the mid-shoal bar configuration unit are calibrated in the configuration interface system; and Based on the calibration results of the configuration interface system, combined with the reflection characteristics of seismic profiles and the comparison rules of well profiles, the vertical stacking and lateral splicing relationships between different configuration units are determined and the sedimentary configuration model is established.

9. The method for characterizing sedimentary configurations according to any one of claims 1-8, characterized in that, Based on the lithological data and the well logging data, the low-frequency, mid-frequency, and high-frequency volumes of each sedimentary layer in the sedimentary configuration model are determined from the seismic data volume to obtain the RGB frequency-separated attribute fusion map of the target work area, including: For each sedimentary layer, the seismic data volume is sliced, and based on the tuning effect and the principle of interlayer interference, low-frequency single-frequency volume, mid-frequency single-frequency volume, and high-frequency single-frequency volume that conform to the distribution characteristics of sand bodies of different thicknesses are selected and determined. Wavelet transform is used to fuse the low-frequency single-frequency body, the mid-frequency single-frequency body, and the high-frequency single-frequency body, and different scales and frequency bands are varied to obtain an RGB frequency division attribute fusion map that meets the requirements of planar resolution and color resolution.

10. The depositional configuration characterization method according to claim 9, characterized in that, The step of extracting the configuration boundary skeleton map from the RGB frequency division attribute fusion map using morphological methods includes: The RGB frequency division attribute fusion map is processed using a morphological gradient algorithm to initially obtain the gradient boundary of the sand body, and the obtained gradient boundary of the sand body is then subjected to threshold processing. Multiple iterative erosion operations are performed along the gradient direction as follows to refine the boundary skeleton from the initially obtained sand body gradient boundary, thus obtaining the configuration boundary skeleton diagram: SEdge = (AΘKB)∠θ - 90° In the formula, SEdge represents the sand body boundary skeleton; A represents the sand body gradient boundary; B represents the structuring element; Θ is the erosion operator; K represents the number of iterations of the erosion operation; and θ represents the direction of the gradient vector at the boundary points on the sand body gradient boundary. It is an empty set.

11. The depositional configuration characterization method according to claim 10, characterized in that, The step of characterizing the boundary features of each of the multiple configuration units within the target work area and the contact features of different configuration units within the multiple configuration units based on the extracted configuration boundary skeleton includes: Based on the distribution characteristics of mudstone and sandstone reflected by the light and dark differences in the RGB attribute fusion diagram, a hierarchical analysis is performed on the sedimentary configuration model to determine the interface of the composite configuration unit in the multiple configuration units. The composite configuration unit includes a composite channel interface or a single braided zone interface. The boundaries of single channel configuration units and / or mid-shoal dam configuration units are determined under the constraints of the interfaces of the composite configuration units, and are used to describe the boundary characteristics of the corresponding configuration units. Combining the sand body thickness distribution characteristics reflected by the chromaticity differences in the RGB attribute fusion diagram and the mudstone distribution characteristics reflected by the configuration boundary framework diagram, the sedimentary configuration model is analyzed to determine the interface of the single channel configuration unit and / or the mid-channel bar configuration unit, and this interface is used to describe the boundary characteristics of the corresponding configuration units; and Analyze the contact relationships between the same or different types of configuration units, and use them to describe the contact characteristics between the corresponding configuration units.

12. A deposition configuration characterization apparatus, characterized in that, include: The sedimentary configuration pattern determination module acquires the sedimentary configuration patterns within the target work area based on well logging data, lithological data, and seismic data volumes. The configuration characterization determination module, based on the lithological data and the well logging data, determines the low-frequency single-frequency volume, mid-frequency single-frequency volume and high-frequency single-frequency volume of each sedimentary layer in the sedimentary configuration model from the seismic data volume, and obtains the RGB frequency-division attribute fusion map of the target work area; The configuration boundary extraction module uses morphological methods to extract the configuration boundary skeleton map from the RGB frequency division attribute fusion map; and The configuration feature characterization module characterizes the boundary features of each of the multiple configuration units in the target work area and the contact features of different configuration units in the multiple configuration units based on the extracted configuration boundary skeleton, so as to complete the deposition configuration characterization in the target work area.

13. A processor, characterized in that, It is configured to perform the deposition configuration characterization method according to any one of claims 1-11.

14. An electronic device, characterized in that, include: A processor, and a memory communicatively connected to the processor; The memory stores computer-executed instructions; The processor executes computer execution instructions stored in the memory to implement the deposition configuration characterization method as described in any one of claims 1-11.

15. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer-executable instructions, which, when executed by a processor, are used to implement the deposition configuration characterization method as described in any one of claims 1-11.

16. A computer program product, characterized in that, It includes a computer program that, when executed by a processor, implements the deposition configuration characterization method according to any one of claims 1-11.

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