Method, apparatus, device, medium and product for sequence stratigraphic correlation

Abstract

The application discloses a kind of layer sequence stratigraphic correlation method, device, equipment, medium and product.Therein, the method comprises: obtaining the well logging data corresponding to the oil well to be analyzed;According to the multiple natural gamma logging values in the well logging data corresponding to the oil well to be analyzed and natural gamma curve, determine the target base level cycle chart corresponding to the oil well to be analyzed;According to target base level cycle chart, the layer sequence stratigraphy of oil well to be analyzed is divided, to determine at least one layer sequence stratigraphic unit corresponding to the oil well to be analyzed;According to the preset feature comparison order, in turn, the layer sequence stratigraphic unit corresponding to the oil well to be analyzed and at least one to be compared layer sequence stratigraphic unit corresponding to the oil well to be compared, which is determined in advance and corresponds to the oil well to be analyzed, are compared in feature, to determine at least one stratigraphic unit matching set corresponding to the oil well to be analyzed.The technical scheme realizes the effect that the layer sequence stratigraphic unit of different oil wells is compared in feature accurately and quickly.

Description

Technical Field

[0001] This invention relates to the field of oil and gas exploration technology, and in particular to a sequence stratigraphic correlation method, apparatus, equipment, medium, and product. Background Technology

[0002] In oil and gas exploration, sequence stratigraphy is a crucial component of petroleum exploration and development research. The delineation of different sequence boundaries and the analysis of their internal cyclic structures are key aspects of sequence stratigraphy. Stratigraphic correlation provides a strong basis for studying the vertical and horizontal variations of reservoirs, identifying the connectivity of oil and gas layers, and finding favorable oil and gas-bearing areas for rational oil and gas field development.

[0003] In related technologies, sequence stratigraphy correlation is typically achieved through manual analysis of well logging data. However, this method involves a significant amount of manual processing, resulting in low efficiency and accuracy. Furthermore, the analysis is highly subjective, prone to arbitrariness, and yields results with multiple interpretations, potentially affecting the reliability of the research. Summary of the Invention

[0004] This invention provides a sequence stratigraphic correlation method, apparatus, equipment, medium, and product to achieve accurate and rapid feature comparison of sequence stratigraphic units in different oil wells.

[0005] According to one aspect of the present invention, a sequence stratigraphy method is provided, the method comprising:

[0006] Acquire logging data corresponding to the oil well to be analyzed; wherein, the logging data is used to characterize the physical properties of the downhole rock formations of the oil well to be analyzed; the logging data includes at least natural gamma curves and natural gamma logging values ​​corresponding to multiple downhole rock formation depths;

[0007] Based on multiple natural gamma logging values ​​and natural gamma curves in the logging data corresponding to the oil well to be analyzed, determine the target reference surface cycloma corresponding to the oil well to be analyzed;

[0008] The oil well to be analyzed is divided into sequence stratigraphic units according to the target reference surface cycle diagram to determine at least one sequence stratigraphic unit corresponding to the oil well to be analyzed.

[0009] According to the preset feature comparison order, the sequence stratigraphic unit corresponding to the oil well to be analyzed and at least one sequence stratigraphic unit corresponding to the oil well to be compared are sequentially compared to determine the matching set of at least one stratigraphic unit corresponding to the oil well to be analyzed.

[0010] According to another aspect of the present invention, a sequence stratigraphy apparatus is provided, the apparatus comprising:

[0011] The data acquisition module is used to acquire logging data corresponding to the oil well to be analyzed; wherein, the logging data is used to characterize the physical properties of the downhole rock formations of the oil well to be analyzed; the logging data includes at least natural gamma curves and natural gamma logging values ​​corresponding to multiple downhole rock formation depths;

[0012] The reference surface cyclone diagram determination module is used to determine the target reference surface cyclone diagram corresponding to the oil well to be analyzed based on multiple natural gamma logging values ​​and natural gamma curves in the logging data corresponding to the oil well to be analyzed.

[0013] The sequence stratigraphic unit division module is used to perform sequence stratigraphic division on the oil well to be analyzed according to the target reference surface cycle diagram, so as to determine at least one sequence stratigraphic unit corresponding to the oil well to be analyzed.

[0014] The sequence stratigraphic comparison module is used to perform feature comparison on the sequence stratigraphic unit corresponding to the oil well to be analyzed and at least one sequence stratigraphic unit corresponding to the oil well to be compared, according to a preset feature comparison order, so as to determine the matching set of at least one stratigraphic unit corresponding to the oil well to be analyzed.

[0015] According to another aspect of the present invention, an electronic device is provided, the electronic device comprising:

[0016] At least one processor; and

[0017] A memory communicatively connected to the at least one processor; wherein,

[0018] The memory stores a computer program that can be executed by the at least one processor, which enables the at least one processor to perform the sequence stratigraphic correlation method according to any embodiment of the present invention.

[0019] According to another aspect of the present invention, a computer-readable storage medium is provided, the computer-readable storage medium storing computer instructions for causing a processor to execute and implement the stratigraphic correlation method according to any embodiment of the present invention.

[0020] According to another aspect of the present invention, a computer program product is provided, the computer program product comprising a computer program that, when executed by a processor, implements the sequence stratigraphic correlation method according to any embodiment of the present invention.

[0021] The technical solution of this invention involves acquiring logging data corresponding to the well to be analyzed. The logging data includes at least a natural gamma curve and natural gamma logging values ​​corresponding to multiple downhole formation depths, facilitating subsequent sequence stratigraphy and sequence stratigraphy comparison. Further, based on the multiple natural gamma logging values ​​and natural gamma curves in the logging data corresponding to the well to be analyzed, a target reference surface cyclomatic diagram corresponding to the well to be analyzed is determined. Further, based on the target reference surface cyclomatic diagram, sequence stratigraphy is performed on the well to be analyzed to determine at least one sequence stratigraphic unit corresponding to the well to be analyzed. Further, according to a preset feature comparison order, the well to be analyzed is sequentially... The corresponding sequence stratigraphic units and at least one pre-determined sequence stratigraphic unit corresponding to the well to be analyzed are compared to determine the matching set of at least one stratigraphic unit corresponding to the well to be analyzed. This solves the problem of low efficiency and accuracy of sequence stratigraphic correlation due to the large amount of manual processing in related technologies. It realizes the effect of automatic segmentation and feature comparison of oil wells based on well logging data, improves the objectivity of sequence stratigraphic segmentation and comparison results, and improves the efficiency and accuracy of sequence stratigraphic correlation. In this way, it can quickly determine the matching set of stratigraphic units, providing a data foundation for subsequent well data analysis between different oil wells.

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

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

[0024] Figure 1 This is a flowchart of a sequence stratigraphic correlation method provided in Embodiment 1 of the present invention;

[0025] Figure 2 This is a schematic diagram of the geological analysis results of a certain section of an oil well to be analyzed, provided in Embodiment 1 of the present invention;

[0026] Figure 3 This is a flowchart of a sequence stratigraphic correlation method provided in Embodiment 2 of the present invention;

[0027] Figure 4This is a schematic diagram of a sequence stratigraphic correlation device according to Embodiment 3 of the present invention;

[0028] Figure 5 This is a schematic diagram of the structure of an electronic device that implements the sequence stratigraphic correlation method of this invention. Detailed Implementation

[0029] 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.

[0030] 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.

[0031] Example 1

[0032] Figure 1 This is a flowchart of a sequence stratigraphic correlation method provided in Embodiment 1 of the present invention. This embodiment is applicable to situations where oil wells are divided into sequence stratigraphic units and feature comparisons are performed between different oil wells. This method can be executed by a sequence stratigraphic correlation device, which can be implemented in hardware and / or software and can be configured in a terminal and / or server. Figure 1 As shown, the method includes:

[0033] S110. Obtain logging data corresponding to the oil well to be analyzed; wherein, the logging data includes at least natural gamma curves and natural gamma logging values ​​corresponding to multiple downhole rock depths.

[0034] The well to be analyzed can be either a well for which well data analysis is to be performed, or a well for which sequence formation comparison analysis is to be performed. The well to be analyzed can be of any type, and this embodiment does not impose any specific limitations on this. Well logging data is used to characterize the physical properties of the downhole formations in the well to be analyzed. It can be understood that well logging data refers to the data and information obtained during drilling by measuring the physical parameters of the downhole formations and the technical condition of the well using various measuring instruments installed in the drill pipe. Well logging data can include multiple aspects, including resistivity logging data, natural gamma logging data, sonic logging data, and formation dip logging data. In this embodiment, the well logging data can at least include natural gamma curves and natural gamma logging values ​​corresponding to multiple downhole formation depths.

[0035] The natural gamma ray curve (NGM) can be used to reflect the distribution and content of radioactive elements in underground rock formations. The NGM curve is obtained by measuring the intensity of gamma rays released during the decay of radioactive elements in underground rock formations. The horizontal axis of the NGM curve typically represents the depth of the rock formation, i.e., the location or depth at which the logging instrument measures the data downhole. This depth can be a relative depth relative to the surface or an absolute depth relative to a specific stratum. The vertical axis of the NGM curve typically represents the intensity or count rate of the natural gamma ray curve, i.e., the number of gamma rays detected by the logging instrument during the measurement process.

[0036] The depth of the rock formation in the well can be a relative depth relative to the surface or an absolute depth relative to a specific stratum. Natural gamma logging values ​​refer to the numerical values ​​obtained by measuring the intensity of natural gamma rays in the rock formation along the wellbore.

[0037] In practice, well logging is performed during oil well exploration to obtain logging data corresponding to the explored well. This logging data, along with the well identifier, is then stored in association. Furthermore, when the well to be analyzed is identified, its identifier can be determined. Further, based on the well identifier, the logging data corresponding to the well to be analyzed can be retrieved from a pre-stored pool of data. Thus, the logging data corresponding to the well to be analyzed can be obtained.

[0038] S120. Based on multiple natural gamma logging values ​​and natural gamma curves in the logging data corresponding to the oil well to be analyzed, determine the target reference surface cyclone diagram corresponding to the oil well to be analyzed.

[0039] The target base level cycle diagram is used to characterize the distribution characteristics of the target base level cycle of the oil well under analysis. These characteristics include the base level cycle period and cycle structure. The target base level cycle diagram can include a medium-term base level cycle diagram and / or a long-term base level cycle diagram. The medium-term base level cycle diagram is used to characterize the distribution characteristics of the medium-term base level cycle of the oil well under analysis. The long-term base level cycle diagram is used to characterize the distribution characteristics of the long-term base level cycle of the oil well under analysis. It can be understood that a base level cycle refers to the rise and fall of the base level relative to sea level, lake level, etc. A complete base level cycle consists of a rising half-cycle and a falling half-cycle. Based on the duration of the base level cycle, it can be divided into short-term, medium-term, and long-term base level cycles. Each higher-order base level cycle is formed by the superposition of several lower-order base level cycles with the same stratigraphic background and sedimentary characteristics. In other words, a long-term datum cycle can be formed by superimposing multiple medium-term datum cycles, and a medium-term datum cycle can be formed by superimposing multiple short-term datum cycles. Generally, in a datum cycle diagram, an equilateral triangle can be used to represent a rising datum, and an inverted triangle to represent a falling datum. For example... Figure 2 This is a schematic diagram of the geological analysis results of a specific section of an oil well to be analyzed, provided in an embodiment of the present invention. For example... Figure 2 As shown, Figure 2 Sub-figure 21 can be a short-term reference surface cycle diagram of a certain well section in the well to be analyzed, and sub-figure 22 can be a medium-term reference surface cycle diagram of a certain well section in the well to be analyzed, which is the target reference surface cycle diagram.

[0040] It should be noted that, in order to compare the sequence stratigraphy of the well to be analyzed, the well can first be divided into sequence stratigraphic units. The change process of the base level cycle is related to the formation distribution in the well to be analyzed. Therefore, a target base level cycle map of the well to be analyzed can be determined first. Then, the sequence stratigraphy of the well to be analyzed can be performed based on the target base level cycle map.

[0041] In this embodiment, in order to obtain the logging data corresponding to the well to be analyzed, the natural gamma logging values ​​and natural gamma curves corresponding to multiple downhole formation depths in the logging data can be acquired. Furthermore, based on the multiple natural gamma logging values ​​and natural gamma curves, a target reference surface cycloma corresponding to the well to be analyzed can be determined.

[0042] S130. Based on the target reference surface cycle, the oil well to be analyzed is divided into sequence stratigraphic units to determine at least one sequence stratigraphic unit corresponding to the oil well to be analyzed.

[0043] It should be noted that the advantage of using intermediate-term and / or long-term base-level cycles for sequence stratigraphy lies in the fact that these cycles, as the basic units of stratigraphy, reflect the sedimentary processes resulting from changes in the base level's position relative to the Earth's surface. Using intermediate-term and / or long-term base-level cycles for stratigraphy can more accurately reflect the sedimentary environment of the strata. Furthermore, the relatively stable periodicity and predictability of intermediate-term and / or long-term base-level cycles make it easier to find similarities between different regions or sections during sequence stratigraphy correlation, thereby improving the accuracy of sequence stratigraphy correlation.

[0044] Sequence stratigraphy units (STLs) are used to characterize stratigraphic sequences with specific sedimentary features and genetic connections. These sequences are divided into different levels of sequence units by unconformities or comparable conformities. In oil well exploration, sequence stratigraphy units provide an accurate stratigraphic correlation framework, helping to predict the distribution of favorable reservoirs and oil and gas reservoir types.

[0045] In this embodiment, given a target reference surface cycle map, sequence stratigraphy can be performed on the well to be analyzed based on the distribution characteristics of the target reference surface cycles included in the target reference surface cycle map. Furthermore, at least one sequence stratigraphic unit corresponding to the well to be analyzed can be obtained.

[0046] Optionally, based on the target reference surface cycle diagram, at least one sequence stratigraphic unit corresponding to the oil well to be analyzed is determined, including: obtaining the lithological profile combination characteristics corresponding to the oil well to be analyzed; and determining at least one sequence stratigraphic unit corresponding to the oil well to be analyzed based on the lithological profile combination characteristics and the reference surface cycle distribution characteristics of the target reference surface cycle diagram.

[0047] Among them, lithological profile assemblage characteristics can be used to characterize the distribution and assemblage of underground strata rocks on a profile. For example, taking a certain profile as an example, the lithological profile assemblage characteristics could be that the upper part of the profile is a siliceous carbonaceous shale section, the middle part is an iron-bearing marl section, and the lower part is an iron-silty sandy shale section. Baseline cyclic distribution characteristics can be the variation morphology and cyclic structure of the baseline cyclic.

[0048] In this embodiment, lithological profile assemblage characteristics can be obtained based on the logging data corresponding to the well to be analyzed. For example, a field query can be used to retrieve the logging data corresponding to the well to be analyzed, thereby obtaining the lithological profile assemblage characteristics. Further, the base surface cycle characteristics can be determined based on the target base surface cycle diagram. Further still, based on the lithological profile assemblage characteristics and the base surface cycle characteristics, the strata can be divided into different sequence stratigraphic units, with the unconformity or its corresponding conformity as the boundary. A sequence stratigraphic unit typically contains a complete base surface cycle or multiple cycles with similar sedimentary characteristics and base surface variation trends. For example, if a significant unconformity is found on the lithological profile, and the lithological assemblage and base surface cycle characteristics above and below it differ significantly, then the unconformity can be used as the sequence boundary to divide the strata above and below into different sequence stratigraphic units. Within each sequence stratigraphic unit, different systems tracts such as the lowstand systems tract, transgressive systems tract, and highstand systems tract are further subdivided based on the rising and falling half-cycles of the base level cycle.

[0049] For example, refer again Figure 2 As shown, Figure 2 Sub-Figure 23 is a schematic diagram of a lithological profile. Sequence stratigraphy is performed based on the lithological profile assemblage characteristics represented by Sub-Figure 23 and the base-level cycle characteristics in the intermediate base-level cycle diagram of Sub-Figure 22. Sub-Figure 22 shows that, based on the standard that a complete base-level cycle consists of an ascending half-cycle and a descending half-cycle, the intermediate base-level cycle diagram can be divided into three complete intermediate base-level cycles. Furthermore, Sub-Figure 23 shows that the lithological profile assemblage characteristics of the first intermediate base-level cycle from top to bottom are mudstone, argillaceous siltstone, medium sandstone, mudstone, medium sandstone, argillaceous siltstone, medium sandstone, and siltstone. The lithology following the last siltstone is mudstone. It can be determined that there is a clear unconformity between the siltstone and mudstone. This unconformity can be used as a sequence boundary to divide the layers above and below this sequence boundary into different sequence stratigraphic units. Based on the above method, three sequence stratigraphic units corresponding to a certain well section in the well to be analyzed can be obtained. The unit numbers of these three sequence stratigraphic units are sequence stratigraphic unit 1, sequence stratigraphic unit 2 and sequence stratigraphic unit 3 in order from high downhole rock depth to low downhole rock depth.

[0050] S140. According to the preset feature comparison order, the sequence stratigraphic unit corresponding to the oil well to be analyzed and at least one sequence stratigraphic unit corresponding to the oil well to be compared are compared in sequence to determine the matching set of at least one stratigraphic unit corresponding to the oil well to be analyzed.

[0051] The feature comparison order can be the order in which sequence stratigraphic features of different oil wells are compared. The feature comparison order can be any predetermined order; optionally, it can be the arrangement order of the sequence stratigraphic units in the oil well to be analyzed. For example, continuing with the previous example, if the arrangement order of the three sequence stratigraphic units corresponding to a certain well section of the oil well to be analyzed is sequence stratigraphic unit 1, sequence stratigraphic unit 2, and sequence stratigraphic unit 3, then the arrangement order of sequence stratigraphic unit 1, sequence stratigraphic unit 2, and sequence stratigraphic unit 3 in the oil well to be analyzed can be used as the feature comparison order. That is, first, the feature comparison of sequence stratigraphic unit 1 is performed, then the feature comparison of sequence stratigraphic unit 2 is performed, and finally the feature comparison of sequence stratigraphic unit 3 is performed.

[0052] The well to be compared can be an oil well whose formation characteristics are to be compared, and this oil well may have the same or similar characteristics as the oil well to be analyzed. It should be noted that the number of oil wells to be compared can be one or more. The sequence stratigraphic unit to be compared can be a sequence stratigraphic unit obtained after dividing the oil wells to be compared into sequence stratigraphic units.

[0053] The stratigraphic unit matching set may include sequence stratigraphic units and sequence stratigraphic units to be matched with the sequence stratigraphic units.

[0054] In this embodiment, a comparison well corresponding to the well to be analyzed can be predetermined, and the comparison well can be divided into sequence stratigraphic units to obtain at least one comparison sequence stratigraphic unit corresponding to the comparison well. Further, when at least one comparison sequence stratigraphic unit corresponding to the well to be analyzed is determined, the sequence stratigraphic unit corresponding to the well to be analyzed can be sequentially compared with the at least one comparison sequence stratigraphic unit corresponding to the comparison well according to a preset feature comparison order. Further, for at least one sequence stratigraphic unit, when a comparison sequence stratigraphic unit matching the sequence stratigraphic unit is determined, the set constructed by the sequence stratigraphic unit and its matching comparison sequence stratigraphic unit can be used as a stratigraphic unit matching set. Thus, at least one stratigraphic unit matching set corresponding to the well to be analyzed can be obtained.

[0055] The technical solution of this invention involves acquiring logging data corresponding to the well to be analyzed. The logging data includes at least a natural gamma curve and natural gamma logging values ​​corresponding to multiple downhole formation depths, facilitating subsequent sequence stratigraphy and sequence stratigraphy comparison. Further, based on the multiple natural gamma logging values ​​and natural gamma curves in the logging data corresponding to the well to be analyzed, a target reference surface cyclomatic diagram corresponding to the well to be analyzed is determined. Further, based on the target reference surface cyclomatic diagram, sequence stratigraphy is performed on the well to be analyzed to determine at least one sequence stratigraphic unit corresponding to the well to be analyzed. Further, according to a preset feature comparison order, the well to be analyzed is sequentially... The corresponding sequence stratigraphic units and at least one pre-determined sequence stratigraphic unit corresponding to the well to be analyzed are compared to determine the matching set of at least one stratigraphic unit corresponding to the well to be analyzed. This solves the problem of low efficiency and accuracy of sequence stratigraphic correlation due to the large amount of manual processing in related technologies. It realizes the effect of automatic segmentation and feature comparison of oil wells based on well logging data, improves the objectivity of sequence stratigraphic segmentation and comparison results, and improves the efficiency and accuracy of sequence stratigraphic correlation. In this way, it can quickly determine the matching set of stratigraphic units, providing a data foundation for subsequent well data analysis between different oil wells.

[0056] An optional technical solution involves determining a target reference surface cyclic diagram corresponding to the oil well to be analyzed based on multiple natural gamma logging values ​​and natural gamma curves from the logging data corresponding to the oil well to be analyzed. This includes: determining the mud-sand ratio curve and sand-mud ratio curve corresponding to the oil well to be analyzed based on multiple natural gamma logging values ​​from the logging data; determining a short-term reference surface cyclic diagram corresponding to the oil well to be analyzed based on the mud-sand ratio curve, sand-mud ratio curve, and natural gamma curve; and determining the target reference surface cyclic diagram corresponding to the oil well to be analyzed based on the short-term reference surface cyclic diagram.

[0057] It should be noted that natural gamma-ray logging values ​​are obtained by measuring the intensity of gamma rays produced by the spontaneous decay of radioactive elements (such as uranium, thorium, and potassium) in rocks. Different rocks have different natural gamma-ray logging values ​​due to variations in the types and amounts of radioactive elements they contain. Furthermore, the lithological characteristics of the well under analysis at different downhole strata depths can be determined based on natural gamma-ray logging values ​​from multiple downhole strata depths. Further, the target reference surface cyclic diagram of the well under analysis can be determined based on the lithological characteristics and the natural gamma-ray curves.

[0058] The mud-to-sand ratio curve reflects the change in the proportion of muddy and sandy sediments in a formation, that is, the ratio of the content of muddy sediments to the content of sandy sediments. The sand-to-mud ratio curve is a direct curve reflecting the proportion of sandy and muddy sediments in a formation, that is, the ratio of the content of sandy sediments to the content of muddy sediments.

[0059] In practical applications, the mud-sand ratio curve can be determined using natural gamma logging values. Specifically, the determination method can be as follows: for multiple downhole formation depths, determine the difference between the natural gamma logging value corresponding to each depth and the minimum natural gamma logging value to obtain a first value; determine the difference between the maximum natural gamma logging value and the natural gamma logging value to obtain a second value; and determine the ratio between the first and second values ​​to obtain the mud-sand ratio value corresponding to the downhole formation depth. Based on the mud-sand ratio values ​​corresponding to multiple downhole formation depths, generate a mud-sand ratio curve corresponding to the well to be analyzed.

[0060] The minimum natural gamma ray logging value can be the natural gamma ray logging value of a pure sandstone formation. The maximum natural gamma ray logging value can be the natural gamma ray logging value of a pure mudstone formation. It should be noted that the minimum and maximum natural gamma ray logging values ​​can be obtained by reading the natural gamma ray logging values ​​of these formations from the logging data after identifying the pure sandstone and pure mudstone formations in the well to be analyzed.

[0061] In practical implementation, after obtaining the natural gamma ray logging values, minimum natural gamma ray logging values, and maximum natural gamma ray logging values ​​corresponding to multiple downhole formation depths based on logging data, for each downhole formation depth, the difference between the natural gamma ray logging value corresponding to the downhole formation depth and the minimum natural gamma ray logging value can be determined, and this difference is used as the first value. Furthermore, the difference between the maximum natural gamma ray logging value and the natural gamma ray logging value corresponding to the downhole formation depth can be determined, and this difference is used as the second value. Further, the ratio between the first value and the second value can be determined, and this ratio is used as the mud-sand ratio value corresponding to the downhole formation depth. Further, after obtaining the mud-sand ratio values ​​corresponding to multiple downhole formation depths, a mud-sand ratio curve corresponding to the well to be analyzed can be generated based on the multiple downhole formation depths and their corresponding mud-sand ratio values.

[0062] In practical applications, the sand-sludge ratio curve of the well to be analyzed can also be determined using natural gamma logging values. The specific determination method is as follows: for multiple downhole formation depths, determine the difference between the maximum natural gamma logging value and the natural gamma logging value corresponding to the downhole formation depth to obtain a third value; determine the difference between the natural gamma logging value and the minimum natural gamma logging value to obtain a fourth value; and determine the ratio between the third value and the fourth value to obtain the sand-sludge ratio value corresponding to the downhole formation depth; based on the sand-sludge ratio values ​​corresponding to multiple downhole formation depths, generate the sand-sludge ratio curve corresponding to the well to be analyzed.

[0063] In practical implementation, after obtaining the natural gamma ray logging values, minimum natural gamma ray logging values, and maximum natural gamma ray logging values ​​corresponding to multiple downhole formation depths based on logging data, for multiple downhole formation depths, the difference between the maximum natural gamma ray logging value and the natural gamma ray logging value corresponding to the downhole formation depth can be determined, and this difference is used as the third value. Furthermore, the difference between the natural gamma ray logging value corresponding to the downhole formation depth and the minimum natural gamma ray logging value can be determined, and this difference is used as the fourth value. Further, the ratio between the third and fourth values ​​can be determined, and this ratio is used as the sand-sludge ratio value corresponding to the downhole formation depth. Further, after obtaining the sand-sludge ratio values ​​corresponding to multiple downhole formation depths, a sand-sludge ratio curve corresponding to the well to be analyzed can be generated based on the multiple downhole formation depths and their corresponding sand-sludge ratio values.

[0064] For example, the mud-to-sand ratio curve and the sand-to-mud ratio curve can be determined based on the following formula:

[0065]

[0066]

[0067] Where RA represents the mud-sand ratio curve; GR represents the natural gamma logging value corresponding to a certain downhole rock depth; GR min This represents the natural gamma-ray logging value of a pure sandstone layer; GR max The value represents the natural gamma ray logging value of a pure mudstone layer; RH represents the sand-mud ratio curve.

[0068] In this embodiment, after obtaining the mud-sand ratio curve and sand-mud ratio curve corresponding to the oil well to be analyzed, the short-term reference surface cyclic diagram corresponding to the oil well to be analyzed can be determined based on the mud-sand ratio curve, sand-mud ratio curve and natural gamma curve.

[0069] An optional technical solution involves determining a short-term reference surface cyclic diagram corresponding to the oil well to be analyzed based on the mud-sand ratio curve, the sand-mud ratio curve, and the natural gamma curve. This includes: determining at least one first stratum depth range when the sand-mud ratio curve and the sand-mud ratio curve meet a first preset condition; for the at least one first stratum depth range, determining the range of first gamma rays corresponding to the natural gamma curve within the first stratum depth range, determining the maximum value within the range of first gamma rays, determining the first stratum depth corresponding to the maximum value, and assigning a first reference surface cyclic point corresponding to the first stratum depth a first value; determining at least one second stratum depth range when the sand-mud ratio curve and the sand-mud ratio curve meet a second preset condition; for the at least one second stratum depth range, determining the range of second gamma rays corresponding to the natural gamma curve within the second stratum depth range, determining the minimum value within the range of second gamma rays, determining the second stratum depth corresponding to the minimum value, and assigning a second reference surface cyclic point corresponding to the second stratum depth a second value; and generating a short-term reference surface cyclic diagram based on the at least one first stratum depth, the first reference surface cyclic point, the second stratum depth, and the second reference surface cyclic point.

[0070] The first preset condition can be that the mud-to-sand ratio value in the mud-to-sand ratio curve is greater than the sand-to-mud ratio value in the sand-to-mud ratio curve. The first rock layer depth range can be a rock layer depth interval composed of multiple downhole rock layer depths, where the mud-to-sand ratio values ​​corresponding to these downhole rock layer depths are all greater than the sand-to-mud ratio values. The first gamma-ray quantity range can be a gamma-ray quantity interval composed of multiple gamma-ray quantities, where these gamma-ray quantities are the natural gamma-ray quantities corresponding to the multiple downhole rock layer depths included in the first rock layer depth range of the natural gamma-ray curve. The first reference surface cycle point can be the highest point of the reference surface rise. The first value can be any value, optionally 0.

[0071] In this embodiment, the mud-to-sand ratio curve and the sand-to-mud ratio curve can be compared. If the mud-to-sand ratio value in the mud-to-sand ratio curve is greater than the sand-to-mud ratio value in the sand-to-mud ratio curve, it can be determined that the sand-to-mud ratio curve and the sand-to-mud ratio curve satisfy a first preset condition. Further, at least one curve segment satisfying the first preset condition can be determined, and the downhole rock depth segment corresponding to each curve segment is taken as a first rock depth range, thereby obtaining at least one first rock depth range. Further, for at least one first rock depth range, the first gamma ray quantity range corresponding to the natural gamma curve in the first rock depth range can be determined. Then, the maximum gamma ray quantity in the first gamma ray quantity range can be determined, and the downhole rock depth corresponding to the determined maximum gamma ray quantity is taken as the first rock depth. Further, the first reference surface rotation point corresponding to the first rock depth can be assigned a first value. For example, refer again... Figure 2 , Figure 2Sub-figure 24 is a schematic diagram of the mud-to-sand ratio curve and the sand-to-mud ratio curve. According to the formulas for the mud-to-sand ratio and sand-to-mud ratio, these two curves are reciprocals of each other. Therefore, when the mud-to-sand ratio in sub-figure 24 is represented by a coordinate system from 0 to 2, the coordinate system from 2 to 0 can represent the sand-to-mud ratio. In other words, the dashed line in sub-figure 24 represents the mud-to-sand ratio curve, and the solid line represents the sand-to-mud ratio curve. Sub-figure 25 is a schematic diagram of the natural gamma ray curve. As can be seen from sub-figure 24, curve segment 241 represents the interval where the mud-to-sand ratio value in the mud-to-sand ratio curve is greater than the sand-to-mud ratio value in the sand-to-mud ratio curve. Therefore, the depth range corresponding to this interval can be taken as the first rock layer depth range. Furthermore, as can be seen from sub-figure 25, the range of the first gamma ray count corresponding to the first rock layer depth range can be range 251. The maximum value within range 251 is determined, and the downhole rock layer depth corresponding to this maximum value is determined to be 2788 meters. 2788 meters is taken as the first rock layer depth.

[0072] The second preset condition can be that the mud-to-sand ratio value in the mud-to-sand ratio curve is less than the sand-to-mud ratio value in the sand-to-mud ratio curve. The second stratum depth range can be a stratum depth interval composed of multiple downhole stratum depths, where the mud-to-sand ratio values ​​corresponding to these downhole stratum depths are all less than the sand-to-mud ratio values. The second gamma-ray quantity range can be a gamma-ray quantity interval composed of multiple gamma-ray quantities, where these gamma-ray quantities are the natural gamma-ray quantities corresponding to the multiple downhole stratum depths included in the second stratum depth range of the natural gamma-ray curve. The second reference surface cycle point can be the lowest point of the reference surface descent. The second value can be any value, optionally 1.

[0073] In this embodiment, if the mud-to-sand ratio value in the mud-to-sand ratio curve is less than the sand-to-mud ratio value in the sand-to-mud ratio curve, it can be determined that the sand-to-mud ratio curve and the sand-to-mud ratio curve satisfy a second preset condition. Further, at least one curve segment satisfying the second preset condition can be determined, and the downhole rock depth segment corresponding to each curve segment can be taken as a second rock depth range, thereby obtaining at least one second rock depth range. Further, for at least one second rock depth range, the second gamma ray quantity range corresponding to the natural gamma curve in the second rock depth range can be determined. Then, the minimum gamma ray quantity in the second gamma ray quantity range can be determined, and the downhole rock depth corresponding to the determined minimum gamma ray quantity is taken as the second rock depth. Further, the second reference surface rotation point corresponding to the second rock depth can be assigned a second value. For example, refer again... Figure 2 , Figure 2Sub-figure 24 shows a schematic diagram of the mud-to-sand ratio curve and the sand-to-mud ratio curve, and sub-figure 25 shows a schematic diagram of the natural gamma ray curve. Sub-figure 24 shows that curve segment 242 represents the interval where the mud-to-sand ratio value in the mud-to-sand ratio curve is less than the sand-to-mud ratio value in the sand-to-mud ratio curve. Therefore, the depth range corresponding to this interval can be taken as the second rock layer depth range. Further, sub-figure 25 shows that the range of the second gamma ray quantity corresponding to the second rock layer depth range can be range 252. The minimum value within range 252 is determined, and the downhole rock layer depth corresponding to this minimum value is determined to be 2768 meters. 2768 meters is then taken as the second rock layer depth.

[0074] Furthermore, after determining at least one first stratum depth, at least one first reference surface cycle point, at least one second stratum depth, and at least one second reference surface cycle point, a short-term reference surface cycle diagram can be generated based on the at least one first stratum depth, the first reference surface cycle point, the second stratum depth, and the second reference surface cycle point. Further, the short-term reference surface cycle diagram can be adjusted based on the lithological profile combination characteristics and the curve trend characteristics of the natural gamma curve of the well to be analyzed. Subsequently, the adjusted reference surface cycle diagram can be used as the target reference surface cycle diagram corresponding to the well to be analyzed.

[0075] Example 2

[0076] Figure 3 This is a flowchart of a sequence stratigraphic correlation method provided in Embodiment 2 of the present invention. Based on the aforementioned embodiments, the feature comparison process of sequence stratigraphic units is further refined. For specific implementation details, please refer to the technical solution of this embodiment. Technical terms that are the same as or similar to those in the above embodiments will not be repeated here.

[0077] like Figure 3 As shown, the method includes:

[0078] S210. Obtain logging data corresponding to the well to be analyzed; wherein, the logging data is used to characterize the physical properties of the downhole rock formations of the well to be analyzed; the logging data includes at least natural gamma curves and natural gamma logging values ​​corresponding to multiple downhole rock formation depths.

[0079] S220. Based on multiple natural gamma logging values ​​and natural gamma curves in the logging data corresponding to the oil well to be analyzed, determine the target reference surface cyclic diagram corresponding to the oil well to be analyzed.

[0080] S230. Based on the target reference surface cycle diagram, perform sequence stratigraphy on the well to be analyzed to determine at least one sequence stratigraphic unit corresponding to the well to be analyzed.

[0081] S240. Determine at least one stratigraphic characteristic parameter corresponding to at least one sequence stratigraphic unit.

[0082] The formation characteristic parameters can be characteristic parameters that characterize the physical properties of the formation. Optionally, the formation characteristic parameters include at least one of porosity, permeability, water saturation, and effective thickness.

[0083] In this embodiment, after determining at least one sequence stratigraphic unit corresponding to the oil well to be analyzed, the logging data corresponding to the oil well to be analyzed can be queried by field querying in order to retrieve at least one formation characteristic parameter corresponding to at least one sequence stratigraphic unit.

[0084] S250. Based on the preset feature comparison order, determine the current sequence stratigraphic unit, and perform feature comparison between at least one stratigraphic feature parameter of the current sequence stratigraphic unit and at least one stratigraphic feature parameter of each sequence stratigraphic unit of the well to be compared.

[0085] The current sequence stratigraphic unit can be the sequence stratigraphic unit currently to be compared.

[0086] In this embodiment, when the current sequence stratigraphic unit to be compared is determined according to the feature comparison order, for at least one sequence stratigraphic unit to be compared corresponding to the oil well to be compared, the current sequence stratigraphic unit and the sequence stratigraphic unit to be compared can be compared based on at least one formation feature parameter corresponding to the current sequence stratigraphic unit and at least one formation feature parameter corresponding to the sequence stratigraphic unit to be compared, so as to obtain the feature comparison result corresponding to the current sequence stratigraphic unit.

[0087] Optionally, feature comparison is performed between at least one stratigraphic feature parameter of the current sequence stratigraphic unit and at least one stratigraphic feature parameter of each sequence stratigraphic unit to be compared in a pre-determined well to be compared. This includes: for at least one sequence stratigraphic unit to be compared, determining a similarity coefficient between the current sequence stratigraphic unit and the sequence stratigraphic unit to be compared based on at least one first stratigraphic feature parameter of the current sequence stratigraphic unit and at least one second stratigraphic feature parameter of the sequence stratigraphic unit to be compared; determining the minimum target similarity coefficient from the at least one similarity coefficient; taking the sequence stratigraphic unit to be compared corresponding to the target similarity coefficient as the target sequence stratigraphic unit that matches the current sequence stratigraphic unit; and taking the current sequence stratigraphic unit and its matching target sequence stratigraphic unit as a stratigraphic unit matching set.

[0088] The similarity coefficient can be a parameter that characterizes the degree of feature similarity between a sequence stratigraphic unit and a sequence stratigraphic unit to be compared. In this embodiment, a lower similarity coefficient indicates a higher degree of similarity between the sequence stratigraphic unit and the sequence stratigraphic unit to be compared. The target similarity coefficient can be the smallest similarity coefficient among at least one similarity coefficient.

[0089] In practical applications, for at least one sequence stratigraphic unit to be compared, at least one first stratigraphic feature parameter of the current sequence stratigraphic unit and at least one second stratigraphic feature parameter of the sequence stratigraphic unit to be compared can be processed to obtain the similarity coefficient between the current sequence stratigraphic unit and the sequence stratigraphic unit to be compared.

[0090] Optionally, based on at least one first stratigraphic feature parameter of the current sequence stratigraphic unit and at least one second stratigraphic feature parameter of the sequence stratigraphic unit to be compared, a similarity coefficient between the current sequence stratigraphic unit and the sequence stratigraphic unit to be compared is determined, including: for at least one first stratigraphic feature parameter, determining the feature value difference corresponding to the first stratigraphic feature parameter based on the first stratigraphic feature parameter and the second stratigraphic feature parameter corresponding to the first stratigraphic feature parameter; and processing the at least one feature value difference through a weighted summation operation or an averaging operation to obtain the similarity coefficient between the current sequence stratigraphic unit and the sequence stratigraphic unit to be compared.

[0091] Here, the eigenvalue difference can be a numerical value characterizing the degree of difference between two feature parameters. The second stratigraphic feature parameter corresponding to the first stratigraphic feature parameter can be two stratigraphic feature parameters with the same feature parameter query field. For example, assuming the first stratigraphic feature parameter is the permeability of the current sequence stratigraphic unit, the corresponding second stratigraphic feature parameter can be the permeability of the sequence stratigraphic unit to be compared.

[0092] In this embodiment, for at least one first stratigraphic feature parameter, a second stratigraphic parameter corresponding to the first stratigraphic feature parameter is determined from at least one second stratigraphic feature parameter of the sequence stratigraphic unit to be compared. Further, the difference between the first and second stratigraphic feature parameters can be determined, and the absolute value of the difference can be determined, with the obtained absolute value used as the first value to be processed. Also, the maximum value between the first and second stratigraphic feature parameters can be determined, and the maximum value can be used as the second value to be processed. Further, the ratio between the first and second values ​​to be processed can be determined, and this ratio can be used as the feature value difference corresponding to the first stratigraphic feature parameter. Further, for at least one feature value difference, a weight corresponding to the feature value difference is determined, and the product between the feature value difference and the weight is determined to obtain the value to be superimposed corresponding to the feature value difference. Then, the at least one value to be superimposed can be added together, and the resulting value can be used as the similarity coefficient between the current sequence stratigraphic unit and the sequence stratigraphic unit to be compared.

[0093] For example, the eigenvalue difference and similarity coefficient can be determined based on the following formula:

[0094]

[0095]

[0096] Where, Δf k (i,j) represents the eigenvalue difference corresponding to the k-th first stratum characteristic parameter; f k (i) represents the first formation characteristic parameter of the kth sequence formation unit of the oil well to be analyzed; f k (j) represents the second formation characteristic parameter of the kth sequence formation unit of the j-th well to be compared; abs() represents calculating the absolute value of a number; D(A i B j ) represents the similarity coefficient between the i-th sequence stratigraphic unit of the well to be analyzed and the j-th sequence stratigraphic unit of the well to be compared; n represents the number of first formation characteristic parameters; w k This represents the weight corresponding to the k-th first stratum characteristic parameter.

[0097] In this embodiment, when the difference in characteristic value corresponding to at least one first stratigraphic characteristic parameter is determined, the difference in characteristic value can be averaged. Then, the average value can be used as the similarity coefficient between the current sequence stratigraphic unit and the sequence stratigraphic unit to be compared.

[0098] In this embodiment, after determining the similarity coefficients between the current sequence stratigraphic unit and each sequence stratigraphic unit to be compared, the smallest similarity coefficient can be determined from at least one similarity coefficient, and this determined similarity coefficient is used as the target similarity coefficient. Furthermore, the sequence stratigraphic unit to be compared corresponding to the target similarity coefficient can be used as the target sequence stratigraphic unit that matches the current sequence stratigraphic unit. Further, the set constructed from the current sequence stratigraphic unit and the target sequence stratigraphic units that match the current sequence stratigraphic unit can be used as the stratigraphic unit matching set corresponding to the well to be analyzed, and this stratigraphic unit matching set can be used as the feature comparison result corresponding to the current sequence stratigraphic unit.

[0099] S260. Update the sequence stratigraphic unit to be compared based on the feature comparison results, and perform feature comparison on the next sequence stratigraphic unit of the current sequence stratigraphic unit based on the updated sequence stratigraphic unit to be compared, until the current sequence stratigraphic unit is the last sequence stratigraphic unit, to obtain at least one set of stratigraphic units matching the oil well to be analyzed.

[0100] In this embodiment, after obtaining the feature comparison results corresponding to the current sequence stratigraphic unit, at least one sequence stratigraphic unit to be compared can be updated according to the feature comparison results.

[0101] Optionally, updating the sequence stratigraphic unit to be compared based on the feature comparison results includes: deleting the target sequence stratigraphic unit that matches the current sequence stratigraphic unit from at least one sequence stratigraphic unit to be compared, and using the deleted sequence stratigraphic unit to be compared as the updated sequence stratigraphic unit to be compared.

[0102] In this embodiment, when a target sequence stratigraphic unit matching the current sequence stratigraphic unit is determined based on feature comparison results, the target sequence stratigraphic unit can be deleted from at least one sequence stratigraphic unit to be compared. Furthermore, the deleted sequence stratigraphic unit can be used as the updated sequence stratigraphic unit to be compared. That is, the target sequence stratigraphic unit matching the current sequence stratigraphic unit is not included in the at least one sequence stratigraphic unit to be compared with the next sequence stratigraphic unit. Further, feature comparison can be performed on the next sequence stratigraphic unit of the current sequence stratigraphic unit based on the updated sequence stratigraphic unit to be compared, until the current sequence stratigraphic unit is the last sequence stratigraphic unit. Then, the resulting stratigraphic unit matching set can be used as at least one stratigraphic unit matching set corresponding to the well to be analyzed.

[0103] The technical solution of this invention involves determining at least one first stratigraphic feature parameter corresponding to at least one sequence stratigraphic unit; further, determining the current sequence stratigraphic unit according to a preset feature comparison order, and comparing the at least one first stratigraphic feature parameter of the current sequence stratigraphic unit with at least one second stratigraphic feature parameter of each sequence stratigraphic unit of the well to be compared; further, updating the sequence stratigraphic unit to be compared based on the feature comparison result, and comparing the next sequence stratigraphic unit of the current sequence stratigraphic unit with the updated sequence stratigraphic unit, until the current sequence stratigraphic unit is the last sequence stratigraphic unit, thus obtaining a matching set of at least one stratigraphic unit corresponding to the well to be analyzed. This achieves the effect of comparing the features of sequence stratigraphic units of different wells based on the stratigraphic parameters of the sequence stratigraphic unit, and achieves the effect of quickly and accurately determining the matching status of sequence stratigraphic units between different wells, providing rich geological background information for subsequent oil and gas exploration.

[0104] Example 3

[0105] Figure 4 This is a schematic diagram of a sequence stratigraphic correlation device provided in Embodiment 3 of the present invention. Figure 4 As shown, the device includes: a data acquisition module 310, a reference surface cycle diagram determination module 320, a sequence stratigraphic unit division module 330, and a sequence stratigraphic comparison module 340.

[0106] The data acquisition module 310 is used to acquire logging data corresponding to the well to be analyzed; wherein the logging data is used to characterize the physical properties of the downhole rock formations of the well to be analyzed; the logging data includes at least a natural gamma curve and natural gamma logging values ​​corresponding to multiple downhole rock formation depths; the reference surface cyclomatic diagram determination module 320 is used to determine a target reference surface cyclomatic diagram corresponding to the well to be analyzed based on multiple natural gamma logging values ​​and the natural gamma curve in the logging data corresponding to the well to be analyzed; sequence stratigraphic unit The segmentation module 330 is used to perform sequence stratigraphic segmentation on the oil well to be analyzed according to the target reference surface cyclic diagram, so as to determine at least one sequence stratigraphic unit corresponding to the oil well to be analyzed; the sequence stratigraphic comparison module 340 is used to perform feature comparison on the sequence stratigraphic unit corresponding to the oil well to be analyzed and at least one sequence stratigraphic unit corresponding to the oil well to be compared in advance, according to a preset feature comparison order, so as to determine a matching set of at least one stratigraphic unit corresponding to the oil well to be analyzed.

[0107] The technical solution of this invention involves acquiring logging data corresponding to the well to be analyzed. The logging data includes at least a natural gamma curve and natural gamma logging values ​​corresponding to multiple downhole formation depths, facilitating subsequent sequence stratigraphy and sequence stratigraphy comparison. Further, based on the multiple natural gamma logging values ​​and natural gamma curves in the logging data corresponding to the well to be analyzed, a target reference surface cyclomatic diagram corresponding to the well to be analyzed is determined. Further, based on the target reference surface cyclomatic diagram, sequence stratigraphy is performed on the well to be analyzed to determine at least one sequence stratigraphic unit corresponding to the well to be analyzed. Further, according to a preset feature comparison order, the well to be analyzed is sequentially... The corresponding sequence stratigraphic units and at least one sequence stratigraphic unit corresponding to the well to be compared with the well to be analyzed are compared to determine the matching set of at least one stratigraphic unit corresponding to the well to be analyzed. This solves the problem that the manual processing workload in related technologies is large, resulting in low efficiency and accuracy of sequence stratigraphic comparison. It realizes the effect of automatic segmentation and feature comparison of oil wells based on well logging data, improves the objectivity of sequence stratigraphic segmentation and comparison results, and improves the efficiency and accuracy of sequence stratigraphic comparison. In this way, it can quickly determine the matching set of stratigraphic units, and provides a data foundation for subsequent oil well data analysis between different oil wells.

[0108] Optionally, the reference surface cycle diagram determination module 320 includes: a mud-sand ratio curve determination unit, a short-term reference surface cycle diagram determination unit, and a target reference surface cycle diagram determination unit.

[0109] The mud-sand ratio curve determination unit is used to determine the mud-sand ratio curve and sand-mud ratio curve corresponding to the oil well to be analyzed based on multiple natural gamma logging values ​​in the logging data.

[0110] The short-term reference surface cyclic diagram determination unit is used to determine the short-term reference surface cyclic diagram corresponding to the oil well to be analyzed based on the mud-sand ratio curve, the sand-mud ratio curve and the natural gamma curve.

[0111] The target reference surface cycle diagram determination unit is used to determine the target reference surface cycle diagram corresponding to the oil well to be analyzed based on the short-term reference surface cycle diagram.

[0112] Optionally, the short-term datum cycle diagram determination unit includes: a first stratum depth range determination subunit, a first datum cycle point assignment subunit, a second stratum depth range determination subunit, a second datum cycle point assignment subunit, and a short-term datum cycle diagram determination subunit.

[0113] The first rock stratum depth range determination subunit is used to determine at least one first rock stratum depth range when the mud-sand ratio curve and the sand-mud ratio curve meet the first preset conditions.

[0114] The first reference surface cyclic point assignment subunit is used to determine, for at least one first rock layer depth range, the first gamma ray number range corresponding to the natural gamma curve in the first rock layer depth range, determine the maximum value in the first gamma ray number range, determine the first rock layer depth corresponding to the maximum value, and assign the first reference surface cyclic point corresponding to the first rock layer depth as a first value.

[0115] The second rock stratum depth range determination subunit is used to determine at least one second rock stratum depth range when the mud-sand ratio curve and the sand-mud ratio curve meet the second preset conditions.

[0116] The second reference surface cyclic point assignment subunit is used to determine the range of the number of second gamma rays corresponding to the natural gamma curve in the range of the second rock layer depth for at least one range of the second rock layer depth, determine the minimum value in the range of the number of second gamma rays, determine the second rock layer depth corresponding to the minimum value, and assign the second reference surface cyclic point corresponding to the second rock layer depth as a second value.

[0117] A short-term reference surface cycle diagram determination sub-unit is used to generate a short-term reference surface cycle diagram based on at least one first stratum depth, the first reference surface cycle point, the second stratum depth, and the second reference surface cycle point.

[0118] Optionally, the sequence stratigraphic unit division module 330 includes: a lithological profile combination feature acquisition unit and a sequence stratigraphic unit division unit.

[0119] The lithological profile combination feature acquisition unit is used to acquire the lithological profile combination features corresponding to the oil well to be analyzed.

[0120] The sequence stratigraphic unit division unit is used to divide the target reference surface cycle map into cycles based on the lithological profile combination characteristics, and to determine at least one sequence stratigraphic unit corresponding to the oil well to be analyzed based on at least one reference surface cycle obtained from the division.

[0121] Optionally, the sequence stratigraphy module 340 includes: a stratigraphic feature parameter determination submodule, a feature comparison submodule, and a stratigraphic unit matching set determination submodule.

[0122] The stratigraphic characteristic parameter determination submodule is used to determine at least one first stratigraphic characteristic parameter corresponding to at least one sequence stratigraphic unit;

[0123] The feature comparison submodule is used to determine the current sequence stratigraphic unit according to the preset feature comparison order, and to perform feature comparison between at least one first stratigraphic feature parameter of the current sequence stratigraphic unit and at least one second stratigraphic feature parameter of each sequence stratigraphic unit of the well to be compared.

[0124] The stratigraphic unit matching set determination submodule is used to update the sequence stratigraphic unit to be compared based on the feature comparison results, and to perform feature comparison on the next sequence stratigraphic unit of the current sequence stratigraphic unit based on the updated sequence stratigraphic unit to be compared, until the current sequence stratigraphic unit is the last sequence stratigraphic unit, so as to obtain at least one stratigraphic unit matching set corresponding to the oil well to be analyzed.

[0125] Optionally, the feature alignment submodule includes: a similarity coefficient determination unit and a feature alignment result determination unit.

[0126] A similarity coefficient determination unit is used to determine, for at least one sequence stratigraphic unit to be compared, the similarity coefficient between the current sequence stratigraphic unit and the sequence stratigraphic unit to be compared, based on at least one first stratigraphic feature parameter of the current sequence stratigraphic unit and at least one second stratigraphic feature parameter of the sequence stratigraphic unit to be compared.

[0127] The feature comparison result determination unit is used to determine the smallest target similarity coefficient from at least one of the similarity coefficients, take the sequence stratigraphic unit to be compared corresponding to the target similarity coefficient as the target sequence stratigraphic unit that matches the current sequence stratigraphic unit, take the current sequence stratigraphic unit and the target sequence stratigraphic unit that matches it as a stratigraphic unit matching set, and take the stratigraphic unit matching set as the feature comparison result corresponding to the current sequence stratigraphic unit.

[0128] Optionally, the similarity coefficient determination unit includes: a feature value difference determination subunit and a similarity coefficient determination subunit.

[0129] The eigenvalue difference determination subunit is used to determine the eigenvalue difference corresponding to at least one first stratigraphic characteristic parameter, based on the first stratigraphic characteristic parameter and a second stratigraphic characteristic parameter corresponding to the first stratigraphic characteristic parameter.

[0130] The similarity coefficient determination sub-unit is used to process at least one of the feature value differences through weighted summation or averaging operations to obtain the similarity coefficient between the current sequence stratigraphic unit and the sequence stratigraphic unit to be compared.

[0131] Optionally, the stratigraphic unit matching set determination submodule includes: sequence stratigraphic unit update unit.

[0132] The sequence stratigraphic unit update unit is used to delete the target sequence stratigraphic unit that matches the current sequence stratigraphic unit from at least one of the sequence stratigraphic units to be compared, and to use the deleted sequence stratigraphic unit to be compared as the updated sequence stratigraphic unit to be compared.

[0133] The sequence stratigraphic correlation apparatus provided in this embodiment of the invention can execute the sequence stratigraphic correlation method provided in any embodiment of the invention, and has the corresponding functional modules and beneficial effects of the method.

[0134] Example 4

[0135] Figure 5A schematic diagram of an electronic device 10 that can be used to implement embodiments of the present invention is shown. The electronic device 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 can also represent various forms of mobile devices, such as personal digital processors, cellular phones, smartphones, wearable devices (e.g., 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.

[0136] like Figure 5 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 may 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.

[0137] 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.

[0138] 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 stratigraphic correlation method.

[0139] In some embodiments, the stratified hierarchical comparison 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 installed 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 stratified hierarchical comparison method described above may be performed. Alternatively, in other embodiments, processor 11 may be configured to perform the stratified hierarchical comparison method by any other suitable means (e.g., by means of firmware).

[0140] 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.

[0141] Computer programs used to implement the methods of the present invention may be written in any combination of one or more programming languages. These computer programs may 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 performed. The computer programs may be executed entirely on a machine, partially on a machine, or as a standalone software package, partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

[0142] 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.

[0143] 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).

[0144] 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), target blockchain networks, and the Internet.

[0145] 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.

[0146] It should be understood that the various forms of processes shown above can be used to reorder, add, or delete steps. 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.

[0147] 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 sequence stratigraphic correlation method, characterized in that, include: Acquire logging data corresponding to the oil well to be analyzed; wherein, the logging data is used to characterize the physical properties of the downhole rock formations of the oil well to be analyzed; the logging data includes at least natural gamma curves and natural gamma logging values ​​corresponding to multiple downhole rock formation depths; Based on multiple natural gamma logging values ​​and natural gamma curves in the logging data corresponding to the oil well to be analyzed, determine the target reference surface cycloma corresponding to the oil well to be analyzed; The oil well to be analyzed is divided into sequence stratigraphic units according to the target reference surface cycle diagram to determine at least one sequence stratigraphic unit corresponding to the oil well to be analyzed. According to the preset feature comparison order, the sequence stratigraphic unit corresponding to the oil well to be analyzed and at least one sequence stratigraphic unit corresponding to the oil well to be compared are sequentially compared to determine the matching set of at least one stratigraphic unit corresponding to the oil well to be analyzed.

2. The sequence stratigraphic correlation method according to claim 1, characterized in that, The step of determining the target reference surface cycle diagram corresponding to the oil well to be analyzed based on multiple natural gamma logging values ​​and natural gamma curves in the logging data corresponding to the oil well to be analyzed includes: Based on multiple natural gamma logging values ​​in the logging data, determine the mud-sand ratio curve and sand-mud ratio curve corresponding to the oil well to be analyzed; Based on the mud-sand ratio curve, the sand-mud ratio curve, and the natural gamma curve, determine the short-term reference surface cycle diagram corresponding to the oil well to be analyzed; Based on the short-term reference surface cycle diagram, determine the target reference surface cycle diagram corresponding to the oil well to be analyzed.

3. The sequence stratigraphic correlation method according to claim 2, characterized in that, The step of determining the short-term reference surface cycle diagram corresponding to the oil well to be analyzed based on the mud-sand ratio curve, the sand-mud ratio curve, and the natural gamma curve includes: If the mud-sand ratio curve and the sand-mud ratio curve meet the first preset conditions, at least one first rock layer depth range is determined; For at least one of the first rock layer depth ranges, determine the range of the number of first gamma rays corresponding to the natural gamma curve in the first rock layer depth range, determine the maximum value in the range of the number of first gamma rays, determine the first rock layer depth corresponding to the maximum value, and assign the first reference surface rotation point corresponding to the first rock layer depth as a first value. If the mud-sand ratio curve and the sand-mud ratio curve meet the second preset condition, at least one second rock layer depth range is determined; For at least one second rock layer depth range, determine the range of second gamma rays corresponding to the natural gamma curve in the second rock layer depth range, determine the minimum value in the range of second gamma rays, determine the second rock layer depth corresponding to the minimum value, and assign the second reference surface cyclic point corresponding to the second rock layer depth as a second value. A short-term reference surface cycle diagram is generated based on at least one first rock stratum depth, the first reference surface cycle point, the second rock stratum depth, and the second reference surface cycle point.

4. The sequence stratigraphic correlation method according to claim 1, characterized in that, The step of determining at least one sequence formation unit corresponding to the oil well to be analyzed based on the target reference surface cycle diagram includes: Obtain the lithological profile combination characteristics corresponding to the oil well to be analyzed; The target reference surface cycle diagram is divided into cycles based on the lithological profile combination characteristics, and at least one sequence stratigraphic unit corresponding to the oil well to be analyzed is determined based on at least one reference surface cycle obtained from the division.

5. The sequence stratigraphic correlation method according to claim 1, characterized in that, The step involves sequentially comparing the sequence stratigraphic unit corresponding to the oil well to be analyzed with at least one sequence stratigraphic unit corresponding to a pre-determined oil well to be compared, according to a preset feature comparison order, to determine a matching set of at least one stratigraphic unit corresponding to the oil well to be analyzed, including: Determine at least one first stratigraphic characteristic parameter corresponding to at least one of the sequence stratigraphic units; Based on the preset feature comparison order, the current sequence stratigraphic unit is determined, and at least one first stratigraphic feature parameter of the current sequence stratigraphic unit is compared with at least one second stratigraphic feature parameter of each sequence stratigraphic unit of the oil well to be compared in the preset comparison order. The sequence stratigraphic unit to be compared is updated based on the feature comparison results. The next sequence stratigraphic unit of the current sequence stratigraphic unit is then compared based on the updated sequence stratigraphic unit to be compared, until the current sequence stratigraphic unit is the last sequence stratigraphic unit, thus obtaining at least one set of stratigraphic units that match the oil well to be analyzed.

6. The sequence stratigraphic correlation method according to claim 5, characterized in that, The step of performing feature comparison between at least one first formation characteristic parameter of the current sequence stratigraphic unit and at least one second formation characteristic parameter of each sequence stratigraphic unit of the well to be compared, as determined in advance, includes: For at least one sequence stratigraphic unit to be compared, a similarity coefficient between the current sequence stratigraphic unit and the sequence stratigraphic unit to be compared is determined based on at least one first stratigraphic feature parameter of the current sequence stratigraphic unit and at least one second stratigraphic feature parameter of the sequence stratigraphic unit to be compared. The minimum target similarity coefficient is determined from at least one of the similarity coefficients. The sequence stratigraphic unit to be compared corresponding to the target similarity coefficient is taken as the target sequence stratigraphic unit that matches the current sequence stratigraphic unit. The current sequence stratigraphic unit and the target sequence stratigraphic unit that matches it are taken as the stratigraphic unit matching set. The stratigraphic unit matching set is taken as the feature comparison result corresponding to the current sequence stratigraphic unit.

7. The sequence stratigraphic correlation method according to claim 6, characterized in that, The step of determining the similarity coefficient between the current sequence stratigraphic unit and the sequence stratigraphic unit to be compared, based on at least one first stratigraphic feature parameter of the current sequence stratigraphic unit and at least one second stratigraphic feature parameter of the sequence stratigraphic unit to be compared, includes: For at least one first stratigraphic feature parameter, the feature value difference corresponding to the first stratigraphic feature parameter is determined based on the first stratigraphic feature parameter and the second stratigraphic feature parameter corresponding to the first stratigraphic feature parameter. The difference in at least one of the eigenvalues ​​is processed by weighted summation or averaging to obtain the similarity coefficient between the current sequence stratigraphic unit and the sequence stratigraphic unit to be compared.

8. The sequence stratigraphic correlation method according to claim 6, characterized in that, The step of updating the sequence stratigraphic unit to be compared based on the feature comparison results includes: The target sequence stratigraphic unit that matches the current sequence stratigraphic unit is deleted from at least one of the sequence stratigraphic units to be compared, and the deleted sequence stratigraphic unit to be compared is used as the updated sequence stratigraphic unit to be compared.

9. A sequence stratigraphic correlation device, characterized in that, include: The data acquisition module is used to acquire logging data corresponding to the oil well to be analyzed; wherein, the logging data is used to characterize the physical properties of the downhole rock formations of the oil well to be analyzed; the logging data includes at least natural gamma curves and natural gamma logging values ​​corresponding to multiple downhole rock formation depths; The reference surface cyclone diagram determination module is used to determine the target reference surface cyclone diagram corresponding to the oil well to be analyzed based on multiple natural gamma logging values ​​and natural gamma curves in the logging data corresponding to the oil well to be analyzed. The sequence stratigraphic unit division module is used to perform sequence stratigraphic division on the oil well to be analyzed according to the target reference surface cycle diagram, so as to determine at least one sequence stratigraphic unit corresponding to the oil well to be analyzed. The sequence stratigraphic comparison module is used to perform feature comparison on the sequence stratigraphic unit corresponding to the oil well to be analyzed and at least one sequence stratigraphic unit corresponding to the oil well to be compared, according to a preset feature comparison order, so as to determine the matching set of at least one stratigraphic unit corresponding to the oil well to be analyzed.

10. 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, the computer program being executed by the at least one processor to enable the at least one processor to perform the sequence stratigraphic correlation method according to any one of claims 1-8.

11. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that cause a processor to execute the stratigraphic correlation method according to any one of claims 1-8.

12. A computer program product, characterized in that, The computer program product includes a computer program that, when executed by a processor, implements the sequence stratigraphic correlation method according to claims 1-8.

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