Evaluation method for hydrocarbon supply range of medium-deep layer hydrocarbon source rock and related device

Abstract

The invention discloses a method for evaluating the hydrocarbon supply range of medium-deep layer hydrocarbon source rocks and a related device, and relates to the technical field of geological exploration and oil and gas development, and the method comprises the following steps: taking the accumulative hydrocarbon generation amount of the hydrocarbon source rocks corresponding to each geological period of a sub-stratum as the initial amount of oil and gas migration; according to an oil-gas migration principle and lithofacies characteristics and fault characteristics in the fault lithofacies diagram of each sub-stratum, simulating an oil-gas migration path and an oil-gas convergence amount of each sub-stratum by utilizing an oil-gas migration geologic model, and determining a hydrocarbon supply range of hydrocarbon source rocks based on the oil-gas migration path and the oil-gas convergence amount; dynamic evaluation of migration paths and convergence ranges of oil and gas on a tectonic plane in different geological periods is realized, so that distribution and potential of oil and gas resources of a middle-deep stratum are accurately evaluated.

Description

Technical Field

[0001] The present application relates to the technical field of geological exploration and oil and gas development, and in particular to an evaluation method and related device for the hydrocarbon supply range of medium-deep hydrocarbon source rocks. Background Art

[0002] Many basins are characterized by high temperature and high pressure, which means that drilling operations in these areas usually only encounter relatively shallow strata. This limitation has led to a relatively weak understanding and recognition of the potential hydrocarbon source kitchen distribution, hydrocarbon generation potential, and hydrocarbon supply range of medium-deep source rocks. Due to the limitation of drilling depth, geologists and petroleum engineers find it difficult to accurately assess the potential of these deep resources, which in turn affects the exploration and development strategies of oil and gas resources. Therefore, a method for systematically and dynamically evaluating the hydrocarbon supply range of medium-deep source rocks is urgently needed. Summary of the invention

[0003] The purpose of this application is to provide a method and related device for evaluating the hydrocarbon supply range of medium-deep source rocks, which can systematically and dynamically evaluate the hydrocarbon supply range of medium-deep source rocks, thereby accurately evaluating the distribution and potential of oil and gas resources in medium-deep strata.

[0004] To achieve the above objectives, this application provides the following solutions:

[0005] In a first aspect, the present application provides a method for evaluating the hydrocarbon supply range of medium-deep source rocks, comprising:

[0006] Obtain lithology data of the basin;

[0007] Establishing a basin lithology three-dimensional data volume according to the lithology data;

[0008] According to the three-dimensional lithology data volume of the basin, the strata of the upper layer of the source rock are divided into a plurality of sub-strata, and a fault lithofacies map of each of the sub-strata is generated;

[0009] The cumulative hydrocarbon generation amount of the source rock corresponding to each geological period of the sub-stratum is used as the starting amount of oil and gas migration, and the oil and gas migration path and oil and gas convergence amount of each sub-stratum are simulated by using the oil and gas migration geological model according to the oil and gas migration principle, the lithofacies characteristics and fault characteristics in the fault lithofacies diagram of each sub-stratum, wherein the cumulative hydrocarbon generation amount is a variable value calculated based on the organic matter abundance of the deep source rock and the hydrocarbon conversion rate in different geological periods;

[0010] The hydrocarbon supply range of the source rock is determined based on the oil and gas migration paths and oil and gas accumulation volumes of all the sub-formations.

[0011] In a second aspect, the present application provides a device for evaluating the hydrocarbon supply range of medium-deep source rocks, comprising:

[0012] A data acquisition module, used to obtain lithology data of the basin;

[0013] A three-dimensional data volume construction module is used to establish a basin lithology three-dimensional data volume according to the lithology data;

[0014] A division module, for dividing the strata of the upper layer of the source rock into a plurality of sub-strata according to the three-dimensional lithology data volume of the basin, and generating a fault lithofacies map of each of the sub-strata;

[0015] The oil and gas migration module is used to use the cumulative hydrocarbon generation of the source rock corresponding to each geological period of the sub-stratum as the starting amount of oil and gas migration, and simulate the oil and gas migration path and oil and gas convergence of each sub-stratum using the oil and gas migration geological model according to the oil and gas migration principle, the lithofacies characteristics and fault characteristics in the fault lithofacies diagram of each sub-stratum, wherein the cumulative hydrocarbon generation is a variable value calculated based on the organic matter abundance of the deep source rock and the hydrocarbon conversion rate in different geological periods;

[0016] The hydrocarbon supply range determination module is used to determine the hydrocarbon supply range of the source rock according to the oil and gas migration paths and oil and gas accumulation amounts of all the sub-formations.

[0017] In a third aspect, the present application provides a computer device comprising: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the method for evaluating the hydrocarbon supply range of medium-deep source rocks as described in the first aspect above.

[0018] In a fourth aspect, the present application provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the method for evaluating the hydrocarbon supply range of medium-deep source rocks described in the first aspect above.

[0019] In a fifth aspect, the present application provides a computer program product, including a computer program, which, when executed by a processor, implements the method for evaluating the hydrocarbon supply range of medium-deep source rocks described in the first aspect above.

[0020] According to the specific embodiments provided in this application, this application discloses the following technical effects:

[0021] The present application provides a method and related device for evaluating the hydrocarbon supply range of medium-deep source rocks. The method takes the cumulative hydrocarbon generation of source rocks corresponding to each geological period of the sub-formation as the starting amount of oil and gas migration, and simulates the oil and gas migration path and oil and gas convergence of each sub-formation according to the oil and gas migration principle, the lithofacies characteristics and fault characteristics in the fault lithofacies diagram of each sub-formation using an oil and gas migration geological model, and determines the hydrocarbon supply range of the source rock based on this, thereby realizing a dynamic evaluation of the migration path and convergence range of oil and gas on the structural surface in different geological periods, thereby accurately evaluating the distribution and potential of oil and gas resources in medium-deep strata. BRIEF DESCRIPTION OF THE DRAWINGS

[0022] In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the drawings required for use in the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative work.

[0023] Figure 1 This is an application environment diagram of a method for evaluating the hydrocarbon supply range of a medium-deep source rock in Example 1 of the present application;

[0024] Figure 2 A schematic flow chart of a method for evaluating the hydrocarbon supply range of a medium-deep source rock provided in Example 1 of the present application;

[0025] Figure 3 This is a schematic diagram of sandstone and mudstone results divided by root mean square amplitude and variance in Example 1 of the present application;

[0026] Figure 4 This is a schematic diagram of the earthquake prediction lithology verification effect in Example 1 of the present application;

[0027] Figure 5 This is a schematic diagram of the TOC verification effect of well logging-seismic prediction in Example 1 of the present application;

[0028] Figure 6 This is a graph showing the methane conversion rate-temperature curve of the source rock layer in Example 1 of the present application;

[0029] Figure 7 The methane reaction fraction-activation energy bar graph of the source rock in Example 1 of the present application;

[0030] Figure 8 This is a schematic diagram of the burial history and thermal history of a single well in Example 1 of the present application;

[0031] Fig. 9 This is a contour map of the current hydrocarbon generation intensity in Example 1 of the present application;

[0032] Fig.10This is a schematic diagram of the structure of the lithology three-dimensional data volume in Example 1 of the present application;

[0033] Fig.11 This is a schematic diagram of the structure of the oil and gas migration geological model in Example 1 of the present application;

[0034] Fig.12 This is a schematic diagram of the oil and gas convergence results in Example 1 of the present application;

[0035] Fig.13 This is a result schematic diagram of the top layer oil and gas migration path in Example 1 of the present application;

[0036] Fig.14 A schematic diagram of the structure of a computer device provided in Example 3 of the present application. DETAILED DESCRIPTION

[0037] The following will be combined with the drawings in the embodiments of the present application to clearly and completely describe the technical solutions in the embodiments of the present application. Obviously, the described embodiments are only part of the embodiments of the present application, not all of the embodiments. Based on the embodiments in the present application, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of this application.

[0038] In order to make the above-mentioned objects, features and advantages of the present application more obvious and easy to understand, the present application is further described in detail below with reference to the accompanying drawings and specific implementation methods.

[0039] Example 1

[0040] The method for evaluating the hydrocarbon supply range of medium-deep source rocks provided in the embodiments of the present application can be applied to Figure 1In the application environment shown. Among them, the terminal 102 communicates with the server 104 through the network. The data storage system can store the data that the server 104 needs to process. The data storage system can be set up separately, integrated on the server 104, or placed on the cloud or other servers. The terminal 102 can send the lithology data of the basin to be processed to the server 104. After receiving the lithology data to be processed, the server 104 divides the strata of the upper layer of the source rock into several sub-strata according to the three-dimensional lithology data body of the basin, and generates a fault lithofacies map of each sub-stratum; the cumulative hydrocarbon generation of the source rock corresponding to each geological period of the sub-stratum is used as the starting amount of oil and gas migration, and according to the oil and gas migration principle, the facies characteristics and fault characteristics in the fault lithofacies map of each sub-stratum, the oil and gas migration geological model is used to simulate the oil and gas migration path and oil and gas convergence of each sub-stratum; according to the oil and gas migration path and oil and gas convergence of all the sub-strata, the hydrocarbon supply range of the source rock is determined. The server 104 can feed back the obtained hydrocarbon supply range to the terminal 102. In addition, in some embodiments, the evaluation method of the hydrocarbon supply range of the medium-deep hydrocarbon source rock can also be implemented by the server 104 or the terminal 102 alone, such as the terminal 102 can directly use the evaluation method of the hydrocarbon supply range of the medium-deep hydrocarbon source rock to process the lithology data to be processed, or the server 104 can obtain the lithology data to be processed from the data storage system and use the evaluation method of the hydrocarbon supply range of the medium-deep hydrocarbon source rock to process it.

[0041] The terminal 102 may be, but is not limited to, various desktop computers, laptop computers, smart phones, tablet computers, IoT devices, and portable wearable devices. The IoT devices may be smart speakers, smart TVs, smart air conditioners, smart vehicle-mounted devices, etc. The portable wearable devices may be smart watches, smart bracelets, head-mounted devices, etc. The server 104 may be implemented as an independent server or a server cluster consisting of multiple servers, or may be a cloud server.

[0042] In an exemplary embodiment, Figure 2 As shown, a method for evaluating the hydrocarbon supply range of medium-deep source rocks is provided. The method is executed by a computer device, and can be executed by a computer device such as a terminal or a server alone, or by a terminal and a server together. In the embodiment of the present application, the method is applied to Figure 1 The server 104 in the example is used as an example to illustrate, including the following steps 201 to 205. Among them:

[0043] Step 201, obtaining lithology data of the basin.

[0044] Step 202: Establish a basin lithology three-dimensional data volume based on the lithology data.

[0045] Step 203: divide the strata of the upper layer of the source rock into a plurality of sub-strata according to the three-dimensional lithology data volume of the basin, and generate a fault lithofacies map of each of the sub-strata.

[0046] Step 204, taking the cumulative hydrocarbon generation of the source rock as the starting amount of oil and gas migration, and simulating the oil and gas migration path and oil and gas accumulation of each sub-formation using an oil and gas migration geological model according to the oil and gas migration principle, the lithofacies characteristics and fault characteristics in the fault lithofacies diagram of each sub-formation, wherein the cumulative hydrocarbon generation is a variable value calculated based on the organic matter abundance and hydrocarbon conversion rate of the deep source rock.

[0047] Step 204 specifically includes:

[0048] Step 204-1, taking the cumulative hydrocarbon generation of the source rock in the first sub-formation geological period as the starting amount of oil and gas migration, simulating oil and gas migration according to the oil and gas migration principle, the lithofacies characteristics and fault characteristics in the fault lithofacies diagram of the first sub-formation, and obtaining the oil and gas convergence amount and migration path of the oil and gas migration to the top surface of the first sub-formation, wherein the first sub-formation is the sub-formation adjacent to the source rock.

[0049] Step 204-2, taking the total amount of oil and gas and the amount of lost hydrocarbon generation in the second sub-formation in the geological period as the starting amount of oil and gas migration, respectively, and performing oil and gas migration according to the oil and gas migration principle, the lithofacies characteristics and the fault characteristics in the fault lithofacies diagram of the second sub-formation, and obtaining the oil and gas convergence amount and migration path of the oil and gas migrated to the top surface of the second sub-formation, wherein each second sub-formation is a sub-formation other than the first sub-formation, and the total amount of oil and gas is a variable calculated based on the oil and gas convergence amount of the third sub-formation in the geological period of the third sub-formation and the oil and gas migration amount of the second sub-formation in the geological period, and the third sub-formation is a sub-formation located below the second sub-formation and adjacent to the second sub-formation, and the first The amount of oil and gas migration in the second sub-formation geological period is the amount of oil and gas convergence obtained by migrating oil and gas to the top surface of the third sub-formation by taking the cumulative hydrocarbon generation of the source rock in the second sub-formation geological period as the starting amount of oil and gas migration, and migrating oil and gas according to the oil and gas migration principle and the lithofacies characteristics and fault characteristics in the fault lithofacies diagram of the fourth sub-formation. The fourth sub-formation is a sub-formation located below the second sub-formation, and the fourth sub-formation includes the third sub-formation. The lost hydrocarbon generation is a variable value calculated based on the cumulative hydrocarbon generation of the fourth sub-formation in the second sub-formation geological period and the migration loss coefficient. The migration loss coefficient is a variable value determined based on the fault sealing property and the sandstone-mudstone ratio of the sub-formation.

[0050] Step 205: Determine the hydrocarbon supply range of the source rock according to the oil and gas migration paths and oil and gas accumulation amounts of all the sub-formations.

[0051] By implementing the above steps 201 to 205, based on the cumulative hydrocarbon generation of deep source rocks in various geological periods, the influence of lithology and fault sealing on oil and gas migration is considered, and combined with the thermal history and burial history of the basin, the migration path and convergence range of oil and gas in the structural surface can be dynamically evaluated in different geological periods. In adjacent strata, the migration and convergence of oil and gas in the lower layer are taken as the new migration starting amount, and after the oil and gas in this layer are quantified, they are migrated to the strata above for the second time. In addition, the oil and gas generated by deep source rocks pass through different strata to determine the migration loss coefficient according to the lithology and fault sealing, so that different strata have oil and gas that meet the geological conditions migrate to the top surface during the corresponding deposition geological period, and the hydrocarbon supply range of oil and gas can be dynamically evaluated.

[0052] In order to make the specific implementation process of the above steps 201 to 205 more clear to those skilled in the art, a specific explanation is given below.

[0053] (1) Determination of organic matter abundance in deep source rocks.

[0054] (1-1) Identify the sandstone and mudstone layers of the virtual well.

[0055] A virtual well that can control the entire work area is established in the well-free area of ​​the basin, and the seismic attributes of the virtual well are extracted. The seismic attributes of the virtual well include root mean square amplitude attributes and variance attributes. The sandstone layer and mudstone layer of the virtual well are identified using a lithology prediction model.

[0056] Specifically, the seismic data of the virtual well is used as input, and the sand-mudstone ratio value is output using the lithology prediction model, wherein the expression of the lithology prediction model is: X=1-A+B, A is the root mean square amplitude attribute, B is the variance attribute, and X is the sand-mudstone ratio value.

[0057] The layer section whose sand-mudstone ratio value is greater than or equal to the threshold is determined as a mudstone layer, and the layer section whose sand-mudstone ratio value is less than the threshold is determined as a sandstone layer.

[0058] According to the characteristics of high RMS amplitude and low variance of seismic attributes corresponding to sandstone and vice versa for mudstone, the seismic attributes of the virtual well are extracted. After normalization, the RMS amplitude attribute is set to A and the variance attribute is set to B. The sand-mudstone ratio of the well is X. The high-value area that satisfies X=1-A+B is the mudstone layer, and the low-value area is the sandstone layer. The schematic diagram of sand-mudstone divided by RMS amplitude and variance is shown in Figure 3 , the prediction and verification results are as follows Figure 4 shown.

[0059] (1-2) Calculation of organic matter abundance in deep source rocks.

[0060] (1-2-1) Taking the sensitive seismic attributes and the lithological attributes of the virtual well as mudstone layers as input, the organic matter abundance prediction model is used to output the organic matter abundance of the mudstone layer of the virtual well, wherein the sensitive seismic attributes include root mean square amplitude attributes, trace integral attributes, variance attributes, average instantaneous frequency attributes and average instantaneous phase attributes, and the organic matter abundance prediction model is a machine learning model.

[0061] This embodiment uses logging-seismic joint prediction of TOC (Total Organic Carbon, organic matter abundance). Specifically, the improved ▲logR method is used. After the accurate acoustic time difference and resistivity logging data are standardized, they are fitted with the measured TOC to predict the TOC of the mudstone layer of a single well. The prediction effect is as follows: Figure 5 shown.

[0062] Select and extract sensitive seismic attributes: root mean square amplitude attribute, trace integral attribute, variance attribute, average instantaneous frequency attribute and average instantaneous phase attribute, extract relevant seismic attributes of virtual wells, combine lithology, and predict TOC of mudstone layer of virtual wells through neural network algorithm in Matlab software. And constrain the prediction results according to measured geochemical data, sedimentary phase and other geological laws.

[0063] (1-2-2) Attribute modeling is performed based on Petrel software, and the organic matter abundance of the deep source rock is obtained according to the organic matter abundance of the mudstone layers of all the virtual wells and the organic matter abundance of the mudstone layers of the measured wells.

[0064] (2) Evaluation of hydrocarbon generation potential of deep source rocks.

[0065] (2-1) Based on several parallel first-order chemical reactions in the hydrocarbon generation process of kerogen samples and the principle of chemical kinetics, a hydrocarbon generation model was established. According to the hydrocarbon generation model and the burial history and thermal history of the single well, the hydrocarbon conversion rate in different geological periods was obtained.

[0066] The chemical kinetics method is used to simulate the kerogen hydrocarbon generation process by using limited parallel first-order reactions, and the kerogen hydrocarbon generation chemical kinetics calibration is performed using the hydrocarbon generation thermal simulation experiment results to establish a hydrocarbon generation model. This embodiment uses a parallel first-order reaction model, which is an existing model.

[0067] Assume that the kerogen (KEO) hydrocarbon generation process consists of a series (NO) of parallel first-order reactions, and the activation energy corresponding to each reaction is EOG i , pre-exponential factor AOG i , and the original potential of kerogen corresponding to each reaction is XOG i0 , i = 1, 2...NO, when the reaction reaches time t, the hydrocarbon generation amount of the i-th reaction is XOG i, R is the molar gas constant, T is the thermodynamic temperature:

[0068]

[0069] At this time, the total gas production of all first-order reactions is:

[0070]

[0071] Among them, NOG is the number of parallel first-order reactions in the oil cracking process; AOG i is the pre-exponential factor; EOG i is the activation energy of the ith reaction; XOG i is the gas production rate of the ith reaction at time t; XOG i0 is the original potential of the ith reaction; KOG i is the reaction rate constant of the ith reaction.

[0072] In this way, once the chemical kinetic parameters of organic matter to hydrocarbons are determined (activation energy, pre-exponential factor, original potential of each reaction or reaction fraction), combined with the temperature and time experienced by the organic matter [reflected by the thermal history T(t) and heating rate D of the organic matter], it is not difficult to quantitatively and dynamically calculate the hydrocarbon conversion rate of the organic matter at any time (temperature).

[0073] Therefore, when applied, the chemical kinetic parameters and thermodynamic temperature in each of the parallel primary chemical reactions are taken as inputs, and the first hydrocarbon conversion rate can be obtained using the hydrocarbon generation model.

[0074] The process of determining chemical kinetic parameters includes:

[0075] The oil-to-gas ratio measured when heating is continued to a certain time t under a certain isothermal experimental condition is set as XOG1 lj , accordingly set the EOG under the same conditions i ,AOG i , XOG i0 , XOG calculated according to the model lj The objective function can be constructed:

[0076]

[0077] Where, LOG is the number of experimental groups. JOG is the number of sampling points on an experimental curve. Q() is the error, XOG lj XOG1 is the oil-to-gas conversion rate calculated by the model of formula (3). lj is the experimentally measured oil-to-gas conversion rate.

[0078] AOG in the formula i and XOGi0 It should also meet the following requirements:

[0079]

[0080] That is, the calibration problem of the model is transformed into the problem of finding the minimum point of the non-negative objective function when satisfying the constraint conditions, i.e., formula (5), and the dynamic problem is converted into a mathematical calculation problem.

[0081] According to the gold tube thermal simulation hydrocarbon generation experimental data, the methane yield of the samples in the target layer was normalized and then calibrated with the chemical kinetic model to obtain the first hydrocarbon conversion rate of the source rock (i.e., the hydrocarbon conversion rate of organic matter at any time and / or temperature). The calibration results are as follows: Figure 6-7 shown.

[0082] Based on the PetroMod2012 basin model software, the burial history and thermal history of a single well are established according to the geological data. Figure 8 As shown, the geological data includes layered data, depth-temperature, depth-maturity parameters (R o ), paleo-water depth, heat flow, sediment-water interface temperature, and lithology data make the R o The data is closer to the measured R o .

[0083] The hydrocarbon conversion rates in different geological periods are obtained according to the first hydrocarbon conversion rate, the burial history and the thermal history.

[0084] (2-2) Calculation of cumulative hydrocarbon generation.

[0085] According to the abundance of organic matter in deep source rocks and the hydrocarbon conversion rate in different geological periods, the hydrocarbon generation rate method based on the hydrocarbon generation mechanism of organic matter is used to calculate the cumulative hydrocarbon generation of source rocks, and the cumulative hydrocarbon generation intensity diagram of each geological period is made to divide the dominant source rock kitchens. Fig. 9 .

[0086] The calculation formula for the cumulative hydrocarbon generation is:

[0087] Q=S·H·ρ·TOC·HI·X(6);

[0088] Where Q is the cumulative hydrocarbon generation (t); S, H and ρ are the areas of source rocks (km 2 ), thickness (m) and density (kg·m -3 ), TOC is the abundance of organic matter in deep source rocks, HI is the hydrogen index, i.e. the original hydrocarbon generation potential per unit mass of organic matter, mg, and X is the hydrocarbon conversion rate of source rocks in different geological periods.

[0089] (3) Dynamic evaluation of the hydrocarbon supply range of source rocks.

[0090] (3-1) The three-dimensional data volume based on lithology prediction is used to accurately depict the fault lithofacies map.

[0091] The lithologic changes of strata have a great influence on the migration of oil and gas. After a set of strata is deposited, it is often distributed in a continuous horizontal direction. Oil and gas generally migrate laterally along the strata. Only when the hydrocarbon column reaches a height where the buoyancy it generates can overcome the capillary force of the overburden, can it migrate vertically. The traditional lithofacies fault map determines the change of capillary force according to the sedimentary phase map of a stratum. The stratum with a thickness of more than one thousand meters is determined as a fixed value by the sedimentary phase plane map of the stratum; and the alluvial fan or delta area is usually assigned a small background value, that is, the capillary force is small, and oil and gas are easy to migrate. But in fact, the distribution of sandstone and mudstone in the alluvial fan or delta of each basin must be different, and the lithologic docking relationship between the upper and lower plates of the fault is also complex, and it is not possible to simply assign a value to determine the magnitude of its capillary force. Therefore, this embodiment studies the prediction of the lithologic data body of the basin based on the Petrel software, and finely depicts the lithologic distribution of the basin. Applying the lithologic three-dimensional data body of step 1, a more detailed lithofacies fault map is obtained to constrain the migration of oil and gas.

[0092] Specifically, this embodiment establishes a basin lithology three-dimensional data body based on the acquired basin lithology data, wherein the lithology data includes measured well lithology data and virtual well lithology data, wherein the virtual well lithology data includes virtual well lithology attributes, and the lithology data body is as follows: Fig.10 shown.

[0093] According to the three-dimensional lithology data volume of the basin, the strata of the upper layer of the source rock are divided into a plurality of sub-strata, and a fault lithofacies map of each of the sub-strata is generated.

[0094] The three-dimensional lithological data body can show the distribution of sandstone and mudstone at any location. After the thick strata are subdivided into thin layers, more detailed lithofacies fault maps can be obtained by subdividing the lithological body into corresponding thin layers, thereby more precisely constraining oil and gas migration.

[0095] (3-2) Dynamically evaluate the hydrocarbon supply range of oil and gas.

[0096] Based on the principle of oil and gas migration (the direction of oil and gas migration is consistent with the direction in which the combined force of buoyancy, pressure and capillary force decreases fastest) and the constraints of the fault lithofacies diagram of the sub-stratum, the cumulative hydrocarbon generation of the source rock corresponding to each geological period of the sub-stratum is taken as the starting amount of oil and gas migration. The oil and gas migration geological model is constructed based on the Trinity basin simulation software, and the oil and gas migration geological model is used to simulate the oil and gas migration. The schematic diagram of the oil and gas migration geological model is shown in the figure. Fig.11 .

[0097] If the A and B strata are developed from bottom to top in the basin, the corresponding geological periods are a and b respectively, and the X source rock is developed under the A layer. After the A layer is deposited, the cumulative hydrocarbon generation in the a period is taken as the starting amount, and the fault lithofacies map of the A layer is used to constrain the migration of oil and gas to the top of the A layer. After the B layer is deposited, two parts of oil and gas will migrate to the top of the B layer. One part is the oil and gas generated in the (ba) period, which first migrates to the top of the A layer under the control of the faults and lithofacies of the A layer. This part of oil and gas is quantitatively added with the oil and gas that migrated to the top of the A layer after the deposition of the A layer, as the starting amount of secondary migration, and migrated to the top of the B layer under the control of the faults and lithofacies of the B layer. The other part is to determine the loss coefficient of oil and gas migration based on the fault sealing property and sandstone-shale ratio of the A layer. The hydrocarbon generation in the (ba) period multiplied by the loss coefficient is regarded as the loss of hydrocarbon generation after the oil and gas is transported to the top of the A layer through the A layer. This is taken as the starting amount and migrated to the top of the B layer under the constraint of the fault lithofacies of the B layer. Finally, the two parts of oil and gas that migrated to the top surface of B are quantitatively added.

[0098] If the basin develops A, B, and C strata from bottom to top, the corresponding geological periods are a, b, and c, respectively, and the X source rock is developed under the A layer, then the A layer and the B layer have the same oil and gas migration process as described above. After the C layer is deposited, two parts of oil and gas will migrate to the top surface of the C layer. One part is the oil and gas generated in the (ca) period, which first migrates to the top surface of the A layer under the control of the faults and lithofacies of the A layer. This part of oil and gas is used as the starting amount and continues to migrate to the top surface of the B layer under the control of the faults and lithofacies of the B layer. At the same time, the oil and gas generated in the (ca) period, after being lost in the A layer, migrates to the top surface of the B layer under the constraints of the faults and lithofacies of the B layer. These oil and gas gathered on the top surface of the B layer in the (ca) period are quantitatively added with the oil and gas that migrated to the top surface of the B layer during the deposition of the B layer, as the starting amount of migration, and migrate to the top surface of the C layer under the control of the faults and lithofacies of the C layer. The other part is to determine the loss coefficient of oil and gas migration based on the fault sealing and sand-shale ratio of layers A and B. The hydrocarbon generation in the (cb) period is multiplied by the loss coefficient and regarded as the loss of hydrocarbon generation after passing through layers A and B and transported to the top surface of layer B. This is taken as the starting amount and migrated to the top surface of layer C under the constraint of the fault lithofacies of layer C. Finally, the two parts of oil and gas migrated to the top surface of layer C are quantitatively added.

[0099] In practical applications, each set of strata can be subdivided, and a lithofacies fault map can be made for each set of strata. The cumulative hydrocarbon generation during the period from the beginning of deposition to the end of deposition of each set of subdivided strata can be used as the starting amount to simulate oil and gas migration. According to the above idea, the migration path to the top layer and the oil and gas accumulation amount can be summed up to divide the favorable exploration area. The oil and gas accumulation amount is as follows: Fig.12 , the oil and gas migration pathways are as follows Fig.13 .

[0100] Since it is difficult to make a detailed evaluation of the entire basin with discrete TOC data in sparse well areas, this embodiment uses the good vertical continuity of well logging data and the good horizontal continuity of seismic data, combined with the TOC data of the measured wells, to jointly predict the TOC of the entire basin, thereby improving the accuracy of TOC prediction for the entire basin. For deep layers that have not been drilled, if there are measured well geochemical data, well logging data and seismic data of the layer around the basin, TOC modeling and prediction can be carried out; the model for predicting TOC using measured well geochemical data, well logging data and seismic data of the middle and shallow layers can also be applied to the deep layers, to evaluate the abundance of organic matter in deep source rocks, and to divide the dominant source kitchens.

[0101] This embodiment is based on the hydrocarbon generation of deep source rocks in various geological periods, takes into account the influence of lithology and fault sealing on oil and gas migration, and combines the thermal history and burial history of the basin to dynamically evaluate the migration path and convergence range of oil and gas on the structural surface in a specific geological period. In adjacent strata, the migration and convergence of oil and gas on the lower surface are used as the new migration starting point. After the oil and gas on this surface are quantified, they are migrated to the strata above for the second time. In addition, the oil and gas generated by deep source rocks pass through different strata to determine the migration loss coefficient according to the lithology and fault sealing, so that different strata have oil and gas that meet the geological conditions migrate to the top surface during the corresponding depositional geological period, and the hydrocarbon supply range of oil and gas can be dynamically evaluated.

[0102] The present application also provides an application scenario, which applies the above-mentioned method for evaluating the hydrocarbon supply range of medium-deep source rocks. Specifically: the method for evaluating the hydrocarbon supply range of medium-deep source rocks provided in this embodiment can be applied in the scenario of oil and gas exploration and development. The scenario includes a geological data collection link, a hydrocarbon supply capacity analysis link, and a resource potential assessment link. The method for evaluating the hydrocarbon supply range of medium-deep source rocks provided in this embodiment is a key technology in the hydrocarbon supply capacity analysis link. Using this method in this embodiment, geologists can more accurately identify oil and gas resource areas with economic value, thereby providing a scientific basis for subsequent drilling and development decisions.

[0103] Based on the same inventive concept, the embodiment of the present application also provides a device for evaluating the hydrocarbon supply range of medium-deep source rocks for implementing the above-mentioned method for evaluating the hydrocarbon supply range of medium-deep source rocks. The implementation scheme for solving the problem provided by the device is similar to the implementation scheme recorded in the above-mentioned method, so the specific limitations in the embodiments of one or more devices for evaluating the hydrocarbon supply range of medium-deep source rocks provided below can refer to the limitations of the method for evaluating the hydrocarbon supply range of medium-deep source rocks above, and will not be repeated here.

[0104] Example 2

[0105] In an exemplary embodiment, a device for evaluating the hydrocarbon supply range of a medium-deep source rock is provided, comprising:

[0106] A data acquisition module, used to obtain lithology data of the basin;

[0107] A three-dimensional data volume construction module is used to establish a basin lithology three-dimensional data volume according to the lithology data;

[0108] A division module, for dividing the strata of the upper layer of the source rock into a plurality of sub-strata according to the three-dimensional lithology data volume of the basin, and generating a fault lithofacies map of each of the sub-strata;

[0109] The oil and gas migration module is used to use the cumulative hydrocarbon generation of the source rock corresponding to each geological period of the sub-stratum as the starting amount of oil and gas migration, and simulate the oil and gas migration path and oil and gas convergence of each sub-stratum using the oil and gas migration geological model according to the oil and gas migration principle, the lithofacies characteristics and fault characteristics in the fault lithofacies diagram of each sub-stratum, wherein the cumulative hydrocarbon generation is a variable value calculated based on the organic matter abundance of the deep source rock and the hydrocarbon conversion rate in different geological periods;

[0110] The hydrocarbon supply range determination module is used to determine the hydrocarbon supply range of the source rock according to the oil and gas migration paths and oil and gas accumulation amounts of all the sub-formations.

[0111] Example 3

[0112] This embodiment provides a computer device, which may be a server or a terminal. Its internal structure diagram may be as follows: Fig.14 As shown. The computer device includes a processor, a memory, an input / output interface (Input / Output, referred to as I / O) and a communication interface. Among them, the processor, the memory and the input / output interface are connected through a system bus, and the communication interface is connected to the system bus through the input / output interface. Among them, the processor of the computer device is used to provide computing and control capabilities. The memory of the computer device includes a non-volatile storage medium and an internal memory. The non-volatile storage medium stores an operating system, a computer program and a database. The internal memory provides an environment for the operation of the operating system and the computer program in the non-volatile storage medium. The database of the computer device is used to store data in the evaluation method for the hydrocarbon supply range of medium-deep hydrocarbon source rocks provided in Example 1. The input / output interface of the computer device is used to exchange information between the processor and an external device. The communication interface of the computer device is used to communicate with an external terminal through a network connection. When the computer program is executed by the processor, the evaluation method for the hydrocarbon supply range of medium-deep hydrocarbon source rocks provided in Example 1 is implemented.

[0113] Those skilled in the art will understand that Fig.14The structure shown in the figure is only a block diagram of a part of the structure related to the solution of the present application, and does not constitute a limitation on the computer device to which the solution of the present application is applied. The specific computer device may include more or fewer components than those shown in the figure, or combine certain components, or have a different arrangement of components.

[0114] Example 4

[0115] This embodiment provides a computer device, including a memory and a processor. The memory stores a computer program. When the processor executes the computer program, it implements the method for evaluating the hydrocarbon supply range of medium-deep source rocks provided in the above-mentioned embodiment 1.

[0116] Example 5

[0117] This embodiment provides a computer-readable storage medium storing a computer program, which, when executed by a processor, implements the method for evaluating the hydrocarbon supply range of medium-deep source rocks provided in the above-mentioned embodiment 1.

[0118] Example 6

[0119] This embodiment provides a computer program product, including a computer program, which, when executed by a processor, implements the method for evaluating the hydrocarbon supply range of medium-deep source rocks provided in the above-mentioned embodiment 1.

[0120] It should be noted that the user information (including but not limited to user device information, user personal information, etc.) and data (including but not limited to data used for analysis, stored data, displayed data, etc.) involved in this application are all information and data authorized by the user or fully authorized by all parties, and the collection, use and processing of relevant data must comply with relevant regulations.

[0121] Those of ordinary skill in the art can understand that all or part of the processes in the above-mentioned embodiment methods can be completed by instructing the relevant hardware through a computer program, and the computer program can be stored in a non-volatile computer-readable storage medium. When the computer program is executed, it can include the processes of the embodiments of the above-mentioned methods. Among them, any reference to the memory, database or other medium used in the embodiments provided in the present application can include at least one of non-volatile and volatile memory. Non-volatile memory can include read-only memory (ROM), magnetic tape, floppy disk, flash memory, optical memory, high-density embedded non-volatile memory, resistive random access memory (ReRAM), magnetic random access memory (MRAM), ferroelectric random access memory (FRAM), phase change memory (PCM), graphene memory, etc. Volatile memory can include random access memory (RAM) or external cache memory, etc. By way of illustration and not limitation, RAM may be in various forms, such as static random access memory (SRAM) or dynamic random access memory (DRAM).

[0122] The database involved in each embodiment provided in this application may include at least one of a relational database and a non-relational database. The non-relational database may include a distributed database based on blockchain, etc., but is not limited thereto. The processor involved in each embodiment provided in this application may be a general-purpose processor, a central processing unit, a graphics processor, a digital signal processor, a programmable logic device, a data processing logic device based on quantum computing, etc., but is not limited thereto.

[0123] The technical features of the above embodiments may be combined arbitrarily. To make the description concise, not all possible combinations of the technical features in the above embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of this specification.

[0124] This article uses specific examples to illustrate the principles and implementation methods of this application. The description of the above embodiments is only used to help understand the method and core ideas of this application. At the same time, for those skilled in the art, according to the ideas of this application, there will be changes in the specific implementation methods and application scope. In summary, the content of this specification should not be understood as limiting this application.

Claims

1. A method for evaluating the hydrocarbon supply range of medium-deep source rocks, characterized in that: The method for evaluating the hydrocarbon supply range of the medium-deep source rock includes: Obtain lithology data of the basin; Establishing a basin lithology three-dimensional data volume according to the lithology data; According to the three-dimensional lithology data volume of the basin, the strata of the upper layer of the source rock are divided into a plurality of sub-strata, and a fault lithofacies map of each of the sub-strata is generated; The cumulative hydrocarbon generation amount of the source rock corresponding to each geological period of the sub-stratum is used as the starting amount of oil and gas migration, and the oil and gas migration path and oil and gas convergence amount of each sub-stratum are simulated by using the oil and gas migration geological model according to the oil and gas migration principle, the lithofacies characteristics and fault characteristics in the fault lithofacies diagram of each sub-stratum, wherein the cumulative hydrocarbon generation amount is a variable value calculated based on the organic matter abundance of the deep source rock and the hydrocarbon conversion rate in different geological periods; The hydrocarbon supply range of the source rock is determined based on the oil and gas migration paths and oil and gas accumulation volumes of all the sub-formations.

2. The method for evaluating the hydrocarbon supply range of medium-deep source rocks according to claim 1, characterized in that: The cumulative hydrocarbon generation of the source rocks corresponding to each geological period of the sub-strata is used as the starting amount of oil and gas migration. According to the oil and gas migration principle, the lithofacies characteristics and fault characteristics in the fault lithofacies diagram of each sub-strata, the oil and gas migration path and oil and gas accumulation of each sub-strata are simulated using the oil and gas migration geological model, which specifically includes: For the first sub-stratum, the cumulative hydrocarbon generation amount of the source rock in the first sub-stratum geological period is used as the starting amount of oil and gas migration, and the oil and gas migration is simulated according to the oil and gas migration principle, the lithofacies characteristics and the fault characteristics in the fault lithofacies diagram of the first sub-stratum, to obtain the oil and gas convergence amount and migration path of the oil and gas migration to the top surface of the first sub-stratum, wherein the first sub-stratum is the sub-stratum adjacent to the source rock; For any second sub-stratum, the total amount of oil and gas and the amount of lost hydrocarbon generation in the second sub-stratum geological period are respectively used as the starting amount of oil and gas migration, and oil and gas migration is performed according to the oil and gas migration principle, the lithofacies characteristics and fault characteristics in the fault lithofacies diagram of the second sub-stratum, and the oil and gas convergence amount and migration path of the oil and gas migrated to the top surface of the second sub-stratum are obtained, wherein each second sub-stratum is a sub-stratum other than the first sub-stratum, and the total amount of oil and gas is a variable calculated based on the oil and gas convergence amount of the third sub-stratum in the geological period of the third sub-stratum and the oil and gas migration amount of the second sub-stratum in the geological period, and the third sub-stratum is a sub-stratum located below the second sub-stratum and adjacent to the second sub-stratum. The oil and gas migration amount of the second sub-formation in the geological period is the oil and gas convergence amount of the oil and gas migrated to the top surface of the third sub-formation by taking the cumulative hydrocarbon generation amount of the source rock in the geological period of the second sub-formation as the starting amount of oil and gas migration, and performing oil and gas migration according to the oil and gas migration principle, the lithofacies characteristics and the fault characteristics in the fault lithofacies diagram of the fourth sub-formation, the fourth sub-formation is all the sub-formations located below the second sub-formation, the lost hydrocarbon generation amount is a variable value calculated according to the cumulative hydrocarbon generation amount of the second sub-formation in the geological period and the migration loss coefficient of the fourth sub-formation, and the migration loss coefficient is a variable value determined according to the fault sealing property and the sandstone-mudstone ratio of the fourth sub-formation.

3. The method for evaluating the hydrocarbon supply range of medium-deep source rocks according to claim 1, characterized in that: The lithology data includes measured well lithology data and virtual well lithology data, and the virtual well lithology data includes virtual well lithology attributes; The specific identification process of the virtual well lithology attribute includes: Acquire seismic attributes of a virtual well, wherein the seismic attributes of the virtual well include root mean square amplitude attributes and variance attributes; The seismic attribute of the virtual well is used as input, and a sand-shale ratio value is outputted using a lithology prediction model, wherein the expression of the lithology prediction model is: X=1-A+B, A is the root mean square amplitude attribute, B is the variance attribute, and X is the sand-shale ratio value; The layer section whose sand-mudstone ratio value is greater than or equal to the threshold is determined as a mudstone layer, and the layer section whose sand-mudstone ratio value is less than the threshold is determined as a sandstone layer.

4. The method for evaluating the hydrocarbon supply range of medium-deep source rocks according to claim 3, characterized in that: The specific calculation process of the organic matter abundance of the deep source rock includes: Taking the sensitive seismic attribute and the virtual well lithology attribute of the mudstone layer as input, the organic matter abundance prediction model is used to output the organic matter abundance of the virtual well mudstone layer, wherein the sensitive seismic attribute includes a root mean square amplitude attribute, a trace integral attribute, a variance attribute, an average instantaneous frequency attribute and an average instantaneous phase attribute, and the organic matter abundance prediction model is a machine learning model; The organic matter abundance of the deep source rock is obtained according to the organic matter abundance of the mudstone layers of all the virtual wells and the organic matter abundance of the mudstone layers of the measured wells.

5. The method for evaluating the hydrocarbon supply range of medium-deep source rocks according to claim 1, characterized in that: The specific calculation process of hydrocarbon conversion rate in different geological periods includes: According to several parallel first-order chemical reactions in the hydrocarbon generation process of kerogen samples, a hydrocarbon generation model is constructed based on the principle of chemical kinetics; Taking the chemical kinetic parameters and thermodynamic temperature in each of the parallel primary chemical reactions as input, and using the hydrocarbon generation model to obtain a first hydrocarbon conversion rate; Establishing the burial and thermal history of a single well based on geological data, wherein the geological data includes stratification data, depth-temperature, depth-maturity parameters, paleo-water depth, heat flow, sediment-water interface temperature, and lithology data; The hydrocarbon conversion rates in different geological periods are obtained according to the first hydrocarbon conversion rate, the burial history and the thermal history.

6. The method for evaluating the hydrocarbon supply range of medium-deep source rocks according to claim 1, characterized in that: The calculation formula for the cumulative hydrocarbon generation is: Q = S·H·ρ·TOC·HI·X; Among them, Q is the cumulative hydrocarbon generation; S, H and ρ are the area, thickness and density of the source rock, respectively; TOC is the abundance of organic matter in deep source rocks; HI is the hydrogen index; and X is the hydrocarbon conversion rate of the source rock in different geological periods.

7. An evaluation device for the hydrocarbon supply range of medium-deep source rocks, characterized in that: The evaluation device for the hydrocarbon supply range of the medium-deep source rock comprises: A data acquisition module, used to obtain lithology data of the basin; A three-dimensional data volume construction module is used to establish a basin lithology three-dimensional data volume according to the lithology data; A division module, for dividing the strata of the upper layer of the source rock into a plurality of sub-strata according to the three-dimensional lithology data volume of the basin, and generating a fault lithofacies map of each of the sub-strata; The oil and gas migration module is used to use the cumulative hydrocarbon generation of the source rock corresponding to each geological period of the sub-stratum as the starting amount of oil and gas migration, and simulate the oil and gas migration path and oil and gas convergence of each sub-stratum using the oil and gas migration geological model according to the oil and gas migration principle, the lithofacies characteristics and fault characteristics in the fault lithofacies diagram of each sub-stratum, wherein the cumulative hydrocarbon generation is a variable value calculated based on the organic matter abundance of the deep source rock and the hydrocarbon conversion rate in different geological periods; The hydrocarbon supply range determination module is used to determine the hydrocarbon supply range of the source rock according to the oil and gas migration paths and oil and gas accumulation amounts of all the sub-formations.

8. A computer device comprising: A memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the method for evaluating the hydrocarbon supply range of medium-deep source rocks as described in any one of claims 1-6.

9. A computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the method for evaluating the hydrocarbon supply range of medium-deep source rocks described in any one of claims 1 to 6 is implemented.

10. A computer program product, comprising a computer program, characterized in that When the computer program is executed by a processor, the method for evaluating the hydrocarbon supply range of medium-deep source rocks described in any one of claims 1 to 6 is implemented.

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