A method and apparatus for identifying fault preferential migration pathways

Abstract

The application discloses a fault dominant migration channel identification method and device. The method comprises the following steps: screening an oil-source fault from a fault system of a research area; determining a relative contact amount of the oil-source fault according to a section area of the oil-source fault and a contact area between the section and a hydrocarbon source rock, and screening a favorable oil-source fault from the oil-source fault according to the relative contact amount; and identifying a fault dominant migration channel according to activity rate distribution data of a main hydrocarbon generation and expulsion period of the favorable oil-source fault and / or a fluid potential energy convergence area. The fault dominant migration channel for oil and gas migration along the fault can be quickly and reasonably screened from the fault system.

Description

Technical Field

[0001] This invention relates to the field of oil and gas exploration technology, and in particular to a method and apparatus for identifying dominant migration channels along faults. Background Technology

[0002] Faults serve as a crucial pathway for secondary hydrocarbon migration. In the lower-source-upper-reservoir accumulation model, multiple layers of mudstone separate the overlying reservoir from the source rock. Hydrocarbons generated from the source rock cannot migrate directly to the overlying reservoir via interconnected sand bodies. In this case, faults are the only pathway connecting the source rock and the overlying reservoir, and are the primary controlling factor for the formation of shallow oil reservoirs located at a significant vertical distance from the source rock. Due to the heterogeneity of fault plane properties and the irregularity of fault geometry, hydrocarbon migration along the fault plane is highly uneven. Therefore, identifying the dominant migration pathways along source fault planes is of significant guiding importance for finding lower-source-upper-reservoir hydrocarbon reservoirs. Research on methods for identifying dominant migration pathways along faults is of great importance for analyzing the distribution patterns of hydrocarbons in shallow oil reservoirs located above source rocks within hydrocarbon basins and for guiding oil and gas exploration. Summary of the Invention

[0003] In view of the above problems, the present invention is proposed to provide a method and apparatus for identifying dominant migration channels of faults that overcomes or at least partially solves the above problems. This method and apparatus can quickly and reasonably screen out favorable oil source faults from the fault system and reasonably identify the dominant migration channels of favorable oil source faults.

[0004] In a first aspect, embodiments of the present invention provide a method for identifying fault-dominant transport channels, comprising:

[0005] Oil-source faults were screened from the fault system in the study area;

[0006] Based on the cross-sectional area of ​​the oil source fault and the contact area between the cross section and the source rock, the relative contact amount of the oil source fault is determined, and favorable oil source faults are selected from the oil source faults based on the relative contact amount.

[0007] Based on the activity rate distribution data and / or fluid potential energy convergence region of the favorable oil source fault during the main hydrocarbon generation and expulsion period, the dominant migration channels of the fault are identified.

[0008] In a second aspect, embodiments of the present invention provide a fault-dominant transport channel identification device, comprising:

[0009] The oil source fault screening module is used to screen oil source faults from the fault system in the study area;

[0010] A favorable oil source fault screening module is used to determine the relative contact amount of the oil source fault based on the cross-sectional area of ​​the oil source fault and the contact area between the cross-section and the source rock, and to screen favorable oil source faults from the oil source faults based on the relative contact amount.

[0011] The dominant migration channel identification module is used to identify the dominant migration channel of the fault based on the activity rate distribution data and / or fluid potential energy convergence area during the main hydrocarbon generation and expulsion period of the favorable oil source fault.

[0012] Thirdly, embodiments of the present invention provide a computer program product for identifying fault-dominant migration channels, including a computer program / instruction, wherein the computer program / instruction, when executed by a processor, implements the above-mentioned fault-dominant migration channel identification method.

[0013] Fourthly, this disclosure provides a server, including: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the program to implement the above-described method for identifying fault-dominant transport channels.

[0014] The beneficial effects of the above-described technical solutions provided in the embodiments of the present invention include at least the following:

[0015] The fault-dominant migration channel identification method provided in this invention identifies favorable oil-source faults based on relative contact volume. A larger relative contact volume indicates a greater amount of oil and gas per unit area of ​​the fault, and a stronger transport capacity of the oil and gas within the fault. Therefore, the selection of favorable oil-source faults is reasonable. Based on the selection of favorable oil-source faults, the method further identifies dominant migration channels based on the activity rate distribution data and / or fluid potential energy convergence areas during the main hydrocarbon generation and expulsion phases of the favorable oil-source faults. A higher activity rate during the main hydrocarbon generation and expulsion phase indicates a stronger ability to transport oil and gas, and oil and gas preferentially migrate in large quantities through fluid potential energy convergence areas. Therefore, in addition to reasonably determining favorable oil-source faults, the method also reasonably identifies dominant migration channels from these favorable faults. Furthermore, the fault-dominant migration channel identification method provided in this invention is easy to implement, simple, and efficient.

[0016] Other features and advantages of the invention will be set forth in the description which follows, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures particularly pointed out in the written description, claims, and drawings.

[0017] The technical solution of the present invention will be further described in detail below with reference to the accompanying drawings and embodiments. Attached Figure Description

[0018] The accompanying drawings are provided to further illustrate the invention and form part of the specification. They are used in conjunction with embodiments of the invention to explain the invention and do not constitute a limitation thereof. In the drawings:

[0019] Figure 1This is a flowchart of the interrupted layer dominant transport channel identification method according to Embodiment 1 of the present invention;

[0020] Figure 2 for Figure 1 The detailed implementation flowchart of step S11;

[0021] Figure 3 for Figure 1 Flowchart of the specific implementation of step S13;

[0022] Figure 4 This is a schematic diagram of the cross-sectional fluid potential type and converging flow in Embodiment 1 of the present invention;

[0023] Figure 5 for Figure 1 The flowchart for the specific implementation of another part of step S13;

[0024] Figure 6 This is a flowchart illustrating the specific implementation of the interrupted layer dominant transport channel identification method in Embodiment 2 of the present invention.

[0025] Figure 7 This is a map showing the fault system and oil source fault distribution in the study area of ​​Embodiment 2 of the present invention;

[0026] Figure 8 This is a cross-sectional contour map of the F1 oil source fault in Embodiment 2 of the present invention;

[0027] Figure 9 This is a histogram showing the activity rate distribution during the main hydrocarbon expulsion period of the F1 oil source fault in Embodiment 2 of the present invention.

[0028] Figure 10 This is a map showing the activity rate distribution of the oil-source fault during the main hydrocarbon expulsion period in Embodiment 2 of the present invention;

[0029] Figure 11 This is a superimposed image of the cross-sectional contour lines and contact area of ​​the F1 oil source fault in Embodiment 2 of the present invention;

[0030] Figure 12 This is the potential energy diagram of the F1 oil source fault fluid in Embodiment 2 of the present invention;

[0031] Figure 13 This is a schematic diagram of the fault-dominant transport channel identification device in an embodiment of the present invention. Detailed Implementation

[0032] Exemplary embodiments of the present disclosure will now be described in more detail with reference to the accompanying drawings. While exemplary embodiments of the present disclosure are shown in the drawings, it should be understood that the present disclosure may be implemented in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the disclosure to those skilled in the art.

[0033] To address the problem of existing technologies failing to identify dominant migration channels along faults, this invention provides a method and apparatus for identifying dominant migration channels along faults, which can quickly and reasonably screen out dominant migration channels for oil and gas along faults from fault systems.

[0034] Example 1

[0035] Embodiment 1 of the present invention provides a method for identifying fault-dominant transport channels, the process of which is as follows: Figure 1 As shown, it includes the following steps:

[0036] Step S11: Screen for oil-source faults from the fault system in the study area.

[0037] For details, see Figure 2 As shown, the following steps may be included:

[0038] Step S111: Screen for faults that break the source rocks and overlying reservoirs from the fault system in the study area.

[0039] The fault system in the study area was carefully analyzed to determine the location and spatial distribution of faults connecting source rocks and overlying reservoirs.

[0040] Step S112: The faults in the selected faults whose main active period matches the main hydrocarbon generation and expulsion period of the source rocks are identified as oil source faults.

[0041] Faults whose main active period coincides with the main hydrocarbon generation and expulsion period of the source rock are analyzed and identified as oil-source faults. Only faults connecting the source rock and the overlying reservoir that are active during the main hydrocarbon generation and expulsion period can become oil-source faults, allowing oil and gas to migrate upwards through the superior migration channels of the fault to the traps in the overlying reservoirs and accumulate into reservoirs.

[0042] Step S12: Determine the relative contact amount of the oil source fault based on the cross-sectional area of ​​the oil source fault and the contact area between the cross-section and the source rock, and screen out favorable oil source faults from the oil source faults based on the relative contact amount.

[0043] The contact area between the fault and the source rock determines, to a certain extent, the fault's ability to accumulate oil and gas at the beginning of its transport. In some embodiments, the area of ​​the fault between the burial depth corresponding to the maturity threshold and the bottom surface of the source rock can be defined as the contact area between the fault and the source rock.

[0044] The relative contact amount of a fault refers to the scale of contact between a unit area of ​​the fault and the source rock. A larger relative contact amount indicates that the fault can provide more oil and gas per unit area, and that the transport channels within the fault have a stronger capacity to migrate oil and gas. Therefore, faults with a relative contact amount greater than a set threshold can be selected as favorable source faults.

[0045] The relative contact amount of the oil source fault can be determined by the following formula:

[0046]

[0047] In the formula, Q represents the relative contact amount between the oil-source fault and the source rock, specifically the relative contact amount between the cross section of the oil-source fault and the source rock, which is dimensionless; T represents the contact area between the cross section and the source rock, in m². 2 S is the cross-sectional area, in meters. 2 .

[0048] Step S13: Identify the dominant migration pathways of the fault based on the activity rate distribution data and / or fluid potential energy convergence areas during the main hydrocarbon generation and expulsion period of the favorable oil source fault.

[0049] The degree of activity at different locations of faults during the hydrocarbon accumulation period (primary hydrocarbon generation and expulsion phase) varies, resulting in different dynamics for transporting hydrocarbons. A higher fault activity rate leads to a stronger ability to transport hydrocarbons. Therefore, it is necessary to calculate the activity rate during the primary hydrocarbon generation and expulsion phase at different locations of favorable oil-source faults to obtain the activity rate distribution data for this phase. For details, see [link to relevant documentation]. Figure 3 As shown, it includes the following steps:

[0050] Step S1311: Cut profiles at set intervals along a direction perpendicular to the strike of the favorable oil source fault.

[0051] Seismic profiles can be extracted from the seismic data volume of the study area at set intervals along a direction perpendicular to the strike of the favorable oil source fault.

[0052] Seismic data volumes can be in the depth domain or the time domain. If the seismic data volume is in the time domain, the location of the seismic line can be read from the seismic profile and the time-depth relationship between adjacent drilled wells within the profile, which is conducive to the fault breaking of the oil source and the fault displacement of the top and bottom interfaces of the sedimentary strata corresponding to the main hydrocarbon generation and expulsion period.

[0053] Alternatively, geological model profiles can be cut from the three-dimensional geological model of the study area at set intervals along a direction perpendicular to the strike of the favorable oil source fault.

[0054] Step S1312: Determine the difference between the bottom and top fault displacements of the sedimentary strata during the main hydrocarbon expulsion period on the profile, and determine the ratio of this difference to the duration of the main hydrocarbon expulsion period as the activity rate of the favorable oil source fault at the boundary with the profile.

[0055] The fault activity rate during the main hydrocarbon generation and expulsion period can be determined by the following formula:

[0056]

[0057] In the formula, V fActivity rate of faults during the main hydrocarbon generation and expulsion period, m / Ma; H b Displacement of the bottom boundary of sedimentary strata during the main hydrocarbon generation and expulsion period, m; H t T represents the top fault displacement of the sedimentary strata during the main hydrocarbon generation and expulsion period, in meters (m); T represents the duration of the main hydrocarbon generation and expulsion period, in ma (years).

[0058] Step S1313: The activity rate distribution data of the favorable oil source fault during the main hydrocarbon generation and expulsion period is composed of the activity rate of the favorable oil source fault at the junction with each profile.

[0059] The identification of the aforementioned fluid potential energy convergence region can be achieved by using cross-sectional depth data of favorable oil source faults to identify the fluid potential energy convergence region from the cross-section. Specifically, this can include the following two methods:

[0060] Method 1: Cross-sectional geometry method.

[0061] See Figure 4 As shown, based on their geometric morphology, cross-sections are classified into straight, concave (upward concave), and convex (upward convex) types. Straight cross-sections have a straight profile, corresponding to a parallel fluid potential; concave cross-sections have an upward concave profile, corresponding to a divergent fluid potential; and convex cross-sections have an upward convex profile, corresponding to a converging fluid potential. Therefore, in concave cross-sections, the fluid potential is divergent, with no dominant migration pathway; in straight cross-sections, the fluid potential decreases parallel, and dominant migration pathways are not obvious; only in convex cross-sections is there a convergent fluid potential flow, possessing a dominant pathway for oil and gas migration.

[0062] Therefore, regions with convex shapes can be identified from the cross-section of favorable oil source faults, and these regions can be identified as fluid potential energy convergence areas.

[0063] The specific cross-sectional geometry can be identified from the cross-sectional iso-depth map.

[0064] Method 2: Cross-sectional fluid potential energy contour normal method.

[0065] See Figure 5 As shown, it includes the following steps:

[0066] Step S1321: Convert the cross-sectional burial depth data volume of the favorable oil source fault into a fluid potential energy data volume.

[0067] The cross-sectional burial depth data of favorable oil source faults is converted into fluid potential energy data using the following formula:

[0068]

[0069] Where Φ is the cross-sectional fluid potential energy, K·J; Z is the cross-sectional burial depth, m; and ρ0 is the crude oil density, g / cm³. 3 g is the acceleration due to gravity, 9.8 m / s².2 p is the cross-sectional fluid pressure, MPa, p = ρ w gZ, ρ w Density of formation water, g / cm³ 3 .

[0070] Step S1322: Obtain the fluid potential energy contour lines of the cross section based on the fluid potential energy data of the cross section.

[0071] Step S1323: Determine several normal lines of the fluid potential energy contour lines, and identify the regions where the normal lines converge from dark to light as fluid potential energy convergence regions.

[0072] The direction of the normal to the contour lines of fluid potential energy in a cross section is the direction in which the fluid potential energy decreases the fastest. When a large number of normals converge at a certain path, a fluid convergence flow is formed, and oil and gas preferentially migrate through this path in large quantities.

[0073] The fault-dominant migration channel identification method provided in Embodiment 1 of this invention screens favorable oil-source faults from oil-source faults based on relative contact volume. A larger relative contact volume indicates more oil and gas can be provided per unit area of ​​the fault, and a stronger transport channel within the fault to transport oil and gas. Therefore, the screening of favorable oil-source faults is reasonable. Based on the screening of favorable oil-source faults, the method further identifies dominant migration channels based on the activity rate distribution data and / or fluid potential energy convergence areas during the main hydrocarbon generation and expulsion phases of the favorable oil-source faults. A higher activity rate during the main hydrocarbon generation and expulsion phases indicates a stronger ability to transport oil and gas, and oil and gas preferentially migrate in large quantities through fluid potential energy convergence areas. Therefore, in addition to reasonably determining favorable oil-source faults, the method also reasonably identifies dominant migration channels from these favorable faults. Furthermore, the fault-dominant migration channel identification method provided in this embodiment of the invention is easy to implement, simple, and efficient.

[0074] Furthermore, if step S13 fails to identify a dominant migration pathway, even if the source fault is identified as a favorable source fault based on the relative contact between the fault surface and the source rock, the fault's characteristics are marked as a non-dominant migration fault. That is, only faults with identified dominant migration pathways are designated as dominant migration faults, while other faults are designated as non-dominant migration faults.

[0075] Example 2

[0076] Embodiment 2 of this invention provides a specific application of the method for identifying dominant migration channels along faults. Taking the ZB region of the SHTL Depression as the research object, the method is used to identify dominant migration channels along fault surfaces. (See [link to documentation]). Figure 6 As shown, it includes the following steps:

[0077] Step S61: Screen oil-source faults from the fault system in the study area.

[0078] Based on high-precision 3D seismic data of the study area, the fault system of the study area was analyzed using fine structural interpretation techniques combined with coherence volume techniques and 3D visualization techniques. The distribution range and orientation of each fault were clarified, and the spatial distribution of the seven faults (F1-F7) connecting source rocks and overlying reservoirs in the study area was confirmed. Figure 7 As shown.

[0079] It has been confirmed that the main active periods of the seven faults all match the main hydrocarbon generation and expulsion periods of the source rocks. Therefore, F1, F2, F3, F4, F5, F6 and F7 are all oil source faults.

[0080] Step S62: Draw the cross-section contour map.

[0081] Based on the finely calibrated seismic composite records, and through well-seismic integration, the time-depth of the oil-source fault planes was converted to the depth domain, and isobath maps of each oil-source fault were drawn. (See also...) Figure 8 The image shown is a contour map of one of the faults (F1 fault).

[0082] Step S63: Determine the activity rate distribution data of the main hydrocarbon generation and expulsion period of the oil source fault.

[0083] Using 3D seismic data, seismic profiles were selected at equal intervals on the seismic plane map. The fault displacement at the top and bottom interfaces of the sedimentary strata corresponding to the main hydrocarbon generation and expulsion periods of the oil-source faults was determined by analyzing the seismic profiles and the time-depth relationship between adjacent drilled wells within the profiles. The activity rates at different locations of each oil-source fault (F1-F7) were calculated using the fault activity rate calculation formula and represented by histograms. (See also...) Figure 9 The figure shows a histogram of the activity rate distribution during the main hydrocarbon expulsion period of an oil-source fault (F1 fault).

[0084] The activity rates of different regions of the oil source faults within the study area were divided into four intervals (0-5 m / Ma, 5-10 m / Ma, 10-15 m / Ma, and >15 m / Ma), and represented by different colors on the plan view (see [reference]). Figure 10 (As shown). The greater the fault activity rate, the stronger its ability to channel oil and gas.

[0085] Step S64: Calculate the relative contact amount between the oil source fault and the source rock.

[0086] The SHTL Depression's main oil-generating trough has an oil-generating threshold, or maturity threshold, corresponding to a burial depth of 1900m. The source rocks are the Arshan Formation, Tengyi Formation, and a small amount of Tengyi Formation above the top of the Paleozoic strata. Using 3D visualization technology, the cross-sectional area of ​​each oil-source fault between the Paleozoic strata and 1900m was calculated to represent the contact area between the oil-source fault and the source rocks. See [link to relevant documentation]. Figure 11 As shown, in Figure 8The contact area between the oil source fault and the source rock is superimposed on the contour map of the oil source fault shown.

[0087] The ratio of the contact area to the cross-sectional area is the relative contact amount (Table 1). The larger the relative contact amount, the stronger the overall ability of the oil source fault to accumulate oil and gas.

[0088] Table 1. Relative Contact Amount Between Oil Source Fault and Source Rock

[0089]

[0090]

[0091] Step S65: Identify the fluid potential energy convergence region from the cross section of the oil source fault.

[0092] Based on the obtained cross-sectional burial depth, the cross-sectional fluid potential energy was calculated using the method described in Example 1. The average crude oil density ρ0 in the ZB area of ​​the SHTL Depression was 0.866 g / cm³. 3 Formation water density ρ w The average value is 1.0268 g / cm³. 3 (Table 2) The cross-sectional fluid potential energy Φ≈21.42×Z; The fluid potential energy contour map was obtained through calculation. On the fluid potential contour map, the migration direction of oil and gas at a certain point is the normal direction of the contour line passing through that point, pointing towards the low potential region. When a large number of point fluid potentials all point towards a certain area and converge in a certain direction and path, this path is a fluid potential energy convergence flow. See also... Figure 12 As shown, normal lines are drawn based on the fluid potential energy contour lines. The region where a large number of normal lines point from the high potential region to the low potential region is the fluid potential energy convergence region.

[0093] Table 2. Statistical table of crude oil density and formation water density in the ZB area of ​​the SHTL Depression.

[0094] well name <![CDATA[Crude oil density ρ0 (g / cm 3 )]]> <![CDATA[Formation water density ρ w (g / cm 3 )]]> S46 0.8369 1.0242 S48 0.8716 1.0331 S54 0.8514 1.0189 S56 0.8719 1.0212 S61 0.8808 1.0279 S63 0.8649 1.0356 S84 0.8843 1.0265 average value 0.8660 1.0268

[0095] To simplify step S65, fluid potential energy convergence areas can also be identified directly from the contour map of the oil source fault using a method line.

[0096] The steps S63 to S65 above have no specific order; any one or two steps can be executed first, or all three steps can be executed simultaneously.

[0097] Step S66: Identify the dominant migration channels of the oil source fault by comprehensively considering the activity rate of the oil source fault, the contact characteristics with the source rock, and the convergence area of ​​fluid potential energy in the fault section.

[0098] The contact characteristics with source rocks specifically refer to the contact area and relative contact amount with source rocks.

[0099] The identification of dominant migration channels in oil-source fault sections can be achieved by prioritizing the relative contact amount between the fault and the source rock, as in Example 1. Only when the relative contact amount condition is met can the activity rate of the fault and the fluid potential energy convergence area of ​​the section be further determined, thereby identifying dominant migration channels from faults that meet the relative contact amount condition. Alternatively, dominant migration channels can be identified by referring to three parameters simultaneously.

[0100] Based on the inventive concept of this invention, embodiments of this invention also provide a fault-dominant transport channel identification device, the structure of which is as follows: Figure 13 As shown, it includes:

[0101] Oil source fault screening module 131 is used to screen oil source faults from the fault system in the study area;

[0102] The favorable oil source fault screening module 132 is used to determine the relative contact amount of the oil source fault based on the cross-sectional area of ​​the oil source fault and the contact area between the cross section and the source rock, and to screen favorable oil source faults from the oil source faults based on the relative contact amount.

[0103] The dominant migration channel identification module 133 is used to identify the dominant migration channel of the fault based on the activity rate distribution data and / or fluid potential energy convergence area during the main hydrocarbon generation and expulsion period of the favorable oil source fault.

[0104] Regarding the apparatus in the above embodiments, the specific manner in which each module performs its operation has been described in detail in the embodiments related to the method, and will not be elaborated upon here.

[0105] Based on the inventive concept of the present invention, embodiments of the present invention also provide a computer program product with fault-dominant migration channel identification function, including a computer program / instruction, wherein the computer program / instruction implements the above-mentioned fault-dominant migration channel identification method when executed by a processor.

[0106] Based on the inventive concept of the present invention, embodiments of the present invention also provide a server, including: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the program to implement the above-mentioned method for identifying fault-dominant transport channels.

[0107] Unless otherwise specifically stated, terms such as processing, calculation, operation, determination, display, etc., may refer to the actions and / or processes of one or more processing or computing systems or similar devices that represent the manipulation and conversion of data representing physical (e.g., electronic) quantities within the registers or memory of the processing system into other data similarly representing physical quantities within the memory, registers, or other such information storage, transmission, or display devices of the processing system. Information and signals can be represented using any of a variety of different techniques and methods. For example, data, instructions, commands, information, signals, bits, symbols, and chips mentioned throughout the above description can be represented by voltage, current, electromagnetic waves, magnetic fields or particles, light fields or particles, or any combination thereof.

[0108] It should be understood that the specific order or hierarchy of steps in the disclosed process is an example of an exemplary method. Based on design preferences, it should be understood that the specific order or hierarchy of steps in the process may be rearranged without departing from the scope of this disclosure. The appended method claims provide elements of various steps in an exemplary order and are not intended to limit the scope to the specific order or hierarchy described.

[0109] In the detailed description above, various features are combined together in a single embodiment to simplify this disclosure. This approach to disclosure should not be construed as reflecting an intention that embodiments of the claimed subject matter require more features than are explicitly stated in each claim. Rather, as reflected in the appended claims, the invention is presented with fewer features than all of the features in a single disclosed embodiment. Therefore, the appended claims are hereby explicitly incorporated into the detailed description, with each claim representing a separate preferred embodiment of the invention.

[0110] Those skilled in the art will also understand that the various illustrative logic blocks, modules, circuits, and algorithm steps described in conjunction with the embodiments herein can be implemented as electronic hardware, computer software, or a combination thereof. To clearly illustrate the interchangeability between hardware and software, the various illustrative components, blocks, modules, circuits, and steps described above are generally described in terms of their functionality. Whether such functionality is implemented as hardware or software depends on the specific application and the design constraints imposed on the overall system. Those skilled in the art can implement the described functionality in alternative ways for each specific application; however, such implementation decisions should not be construed as departing from the scope of this disclosure.

[0111] The steps of the methods or algorithms described in conjunction with the embodiments herein can be directly embodied in hardware, software modules executed by a processor, or a combination thereof. The software modules can reside in RAM memory, flash memory, ROM memory, EPROM memory, EEPROM memory, registers, hard disks, removable disks, CD-ROMs, or any other form of storage medium well known in the art. An exemplary storage medium is connected to the processor, enabling the processor to read information from and write information to the storage medium. Of course, the storage medium can also be a component of the processor. The processor and storage medium can reside in an ASIC. The ASIC can reside in a user terminal. Alternatively, the processor and storage medium can exist as discrete components in the user terminal.

[0112] For software implementation, the techniques described in this application can be implemented using modules (e.g., procedures, functions, etc.) that perform the functions described in this application. This software code can be stored in memory units and executed by a processor. The memory units can be implemented within the processor or outside the processor; in the latter case, they are communicatively coupled to the processor via various means, as is well known in the art.

[0113] The foregoing description includes examples of one or more embodiments. It is certainly impossible to describe all possible combinations of components or methods in order to describe the above embodiments, but those skilled in the art will recognize that further combinations and arrangements of the various embodiments are possible. Therefore, the embodiments described herein are intended to cover all such changes, modifications, and variations that fall within the scope of the appended claims. Furthermore, the term "comprising" as used in the specification or claims is interpreted in a manner similar to the term "including," as interpreted when used as a conjunction in the claims. Additionally, the use of any term "or" in the specification of the claims is intended to mean "non-exclusive or."

Claims

1. A method for identifying fault-dominant transport channels, characterized in that, include: Oil-source faults were screened from the fault system in the study area; Based on the cross-sectional area of ​​the oil source fault and the contact area between the cross section and the source rock, the relative contact amount of the oil source fault is determined, and favorable oil source faults are selected from the oil source faults based on the relative contact amount. Based on the activity rate distribution data and / or fluid potential energy convergence area of ​​the favorable oil source fault during the main hydrocarbon generation and expulsion period, the dominant migration channel of the fault is identified. The contact area between the cross section and the source rock is determined in the following manner: The area of ​​the cross section sandwiched between the burial depth corresponding to the maturity threshold and the bottom surface of the source rock is determined as the contact area between the cross section and the source rock. The activity rate distribution data of the favorable oil source fault during the main hydrocarbon generation and expulsion period were determined in the following manner: Sections are cut at predetermined intervals along a direction perpendicular to the strike of the favorable oil source fault; the difference between the bottom and top fault displacements of the sedimentary strata during the main hydrocarbon expulsion period on the section is determined, and the ratio of the difference to the duration of the main hydrocarbon expulsion period is determined as the activity rate of the favorable oil source fault at the interface with the section; the activity rate of the favorable oil source fault at the interface with each section constitutes the activity rate distribution data of the main hydrocarbon generation and expulsion period of the favorable oil source fault.

2. The method as described in claim 1, characterized in that, The determination of the relative contact amount of the oil-source fault based on the cross-sectional area of ​​the fault and the contact area between the cross-section and the source rock specifically includes: The ratio of the contact area between the cross section of the oil source fault and the source rock to the cross section area is determined as the relative contact amount of the oil source fault.

3. The method as described in claim 1 or 2, characterized in that, The process of screening favorable oil-source faults from oil-source faults based on relative contact amount specifically includes: Oil source faults with a relative contact amount greater than a set relative contact amount threshold are selected as favorable oil source faults.

4. The method as described in claim 1, characterized in that, The step of cutting cross-sections at predetermined intervals along a direction perpendicular to the strike of the favorable oil source fault specifically includes: Seismic profiles are extracted from the seismic data volume of the study area at predetermined intervals along a direction perpendicular to the strike of the favorable oil source fault; or... From the three-dimensional geological model of the study area, geological model profiles are cut at set intervals along a direction perpendicular to the strike of the favorable oil source fault.

5. The method as described in claim 1, characterized in that, The fluid potential energy convergence region of the favorable oil source fault is determined by the following method: Based on the cross-sectional burial depth data of the favorable oil source fault, fluid potential energy convergence regions are identified from the cross-section.

6. The method as described in claim 5, characterized in that, The step of identifying fluid potential energy convergence regions from the cross-section based on the cross-sectional depth data of the favorable oil source fault specifically includes: Based on the cross-sectional burial depth data of the favorable oil source fault, regions with convex shapes are identified from the cross-section of the favorable oil source fault, and these regions are identified as fluid potential energy convergence regions.

7. The method as described in claim 5, characterized in that, The step of identifying fluid potential energy convergence regions from the cross-section based on the cross-sectional depth data of the favorable oil source fault specifically includes: The cross-sectional burial depth data of the favorable oil source fault is converted into cross-sectional fluid potential energy contour lines. Several normals to the contour lines are determined, and regions where the normals converge from dark to light are identified as fluid potential energy convergence regions.

8. The method as described in claim 7, characterized in that, The process of converting the cross-sectional burial depth data of the favorable oil source fault into cross-sectional fluid potential energy contour lines specifically includes: The cross-sectional burial depth data of the favorable oil source fault is converted into a fluid potential energy data volume using the following formula: ； Where Φ is the cross-sectional fluid potential energy; Z is the cross-sectional burial depth; Where is the density of crude oil; g is the acceleration due to gravity; p is the cross-sectional fluid pressure. , Density of formation water; Draw the fluid potential energy contour lines of the cross section based on the fluid potential energy data volume of the cross section.

9. The method as described in claim 1, characterized in that, The screening of oil-source faults from the fault system in the study area specifically includes: Faults that break through source rocks and overlying reservoirs were screened from the fault system in the study area; Faults whose main active period matches the main hydrocarbon generation and expulsion period of the source rocks in the selected faults are identified as oil-source faults.

10. The method according to any one of claims 1, 2, and 5 to 9, characterized in that, The identified fault-dominant transport pathway also includes: If no dominant migration pathway is identified along the fault, the favorable oil source fault is marked as a non-dominant migration fault.

11. A fault-dominant transport channel identification device, characterized in that, include: The oil source fault screening module is used to screen oil source faults from the fault system in the study area; A favorable oil source fault screening module is used to determine the relative contact amount of an oil source fault based on its cross-sectional area and the contact area between the cross-section and the source rock, and to screen favorable oil source faults from the oil source faults based on the relative contact amount. The contact area between the cross-section and the source rock is determined by the following method: the area of ​​the cross-section sandwiched between the burial depth corresponding to the maturity threshold and the bottom surface of the source rock is determined as the contact area between the cross-section and the source rock. The dominant migration channel identification module is used to identify the dominant migration channel of the fault based on the activity rate distribution data and / or fluid potential energy convergence area of ​​the dominant oil-source fault during the main hydrocarbon generation and expulsion period. The activity rate distribution data of the dominant oil-source fault during the main hydrocarbon generation and expulsion period is determined by: taking profiles at set intervals along a direction perpendicular to the strike of the dominant oil-source fault; determining the difference between the bottom and top fault displacements of the sedimentary strata during the main hydrocarbon expulsion period on the profile; and determining the ratio of the difference to the duration of the main hydrocarbon expulsion period as the activity rate of the dominant oil-source fault at the interface with the profile. The activity rate of the dominant oil-source fault at the interface with each profile constitutes the activity rate distribution data of the dominant oil-source fault during the main hydrocarbon generation and expulsion period.

12. A computer program product with fault-preferred transport channel identification function, comprising a computer program / instructions, characterized in that, When the computer program / instruction is executed by the processor, it implements the fault-dominant transport channel identification method according to any one of claims 1 to 10.

13. A server, characterized in that, include: A memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor, when executing the program, implements the fault-dominant migration channel identification method according to any one of claims 1 to 10.

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