A method and device for carving fracture-cavity of a fracture-cavity carbonate reservoir

Abstract

The application provides a fracture-cave carving method and device for a fracture-cave carbonate reservoir, and the method comprises the following steps: according to a determined fracture-cave reservoir identification result and pre-acquired well data, a seismic wave impedance inversion is constrained to obtain a wave impedance body, and a static profile volume and an average wave impedance value of a constant-volume cave reservoir are carved; according to a calculated dynamic reserve of the constant-volume cave reservoir, the static profile volume and the average wave impedance value, an average porosity value is calculated, a wave impedance-porosity equivalent model is established, a plurality of cave models and a plurality of dissolved pore models are established; a seismic fracture is predicted, and a plurality of fracture models are established; based on an inter-well connectivity relationship, a plurality of equal-probability fracture-cave reservoir carving models obtained through fusion are screened to obtain at least one preferred fracture-cave reservoir carving model. Through the combination of dynamic data and static data, the fracture-cave carving uncertainty is reduced, and the fracture-cave carving precision is improved.

Description

Technical Field

[0001] This invention relates to the field of carbonate oil and gas reservoir development technology, and more specifically, to a method and apparatus for fracture-vuggy carbonate oil reservoirs. Background Technology

[0002] The reservoir types of fracture-cavity reservoirs are mainly cave-type and fracture-cavity type. Taking the Tarim Basin as an example, its Ordovician carbonate rocks are old, deeply buried and large in scale. They have undergone multiple tectonic movements and karstification, resulting in the development of dissolution pores, fractures and caves, forming fracture-cavity reservoirs (for details, please refer to Zhao Wenzhi et al., Research on the Types of Carbonate Rock Karst Reservoirs and Their Guiding Significance for Exploration: Taking the Karst Reservoirs in the Tarim Basin as an Example, Acta Petrologica Sinica, 2013, 29(9):3213-3222; He Zhiliang et al., Characteristics of Oil and Gas Accumulation in Marine Ultra-Deep Carbonate Rocks in China and Exploration Fields, China Petroleum Exploration, 2016, 21(1):3-14). They lack the facies control law of clastic oil reservoirs and have strong heterogeneity. Due to the limited size of individual fractured cavities and their large burial depth, the planar response range is very limited. They are also affected by multiple diffraction waves in the longitudinal direction, making seismic identification difficult (for details, please refer to Yang et al., Analysis of Key Factors Affecting Seismic Reflection Characteristics of Karst Fractured Cavities, Petroleum Geophysical Exploration, 2015, 50(3):523-529). Among them, large cave-type reservoirs exhibit strong amplitude characteristics of "beaded" in seismic data and are the main drilling targets; small pore-type reservoirs and fracture-type reservoirs are difficult to identify directly in seismic data, and fractures mainly play the role of connecting reservoirs (for details, please refer to Ni Xinfeng et al., Geological Modeling of High-Quality Carbonate Fractured-Cavity Reservoirs: Taking the Ordovician System of the North Slope of the Central Tarim Basin and the South Margin of the Northern Tarim Basin as an Example, Petroleum Exploration and Development, 2013, 40(4):414-422).

[0003] Fractured-vuggy carbonate reservoirs exhibit a "one-vuggy-one-reservoir" phenomenon, meaning that the oil-water interface is consistent within the same fractured-vuggy reservoir, but not uniform across multiple adjacent fractured-vuggy reservoirs. The characteristics of fractured-vuggy carbonate reservoirs, such as deep burial, severe heterogeneity, diverse reservoir types, and exceptionally complex oil-water relationships, make reservoir understanding and development extremely difficult. Oilfield development faces challenges including low drilling success rates, rapid production decline, difficulty in selecting energy replenishment methods, poor development effects, and recovery rates below 15%, posing numerous challenges to achieving large-scale, efficient development and long-term stable production.

[0004] Fracture-vuggy sculpting is the quantitative characterization of the spatial distribution, morphology, and connectivity of fracture-vuggy reservoirs. It establishes a geological model that objectively reflects the characteristics of effective reservoirs, providing a basis for reservoir prediction, reserve evaluation, drilling and completion, and adjustments to development measures. Because engineering anomalies such as "venting" or "leakage" often occur in fracture-vuggy development sections during drilling, core and logging data cannot be effectively obtained. Therefore, current fracture-vuggy sculpting techniques are generally based on static seismic information and extremely limited logging data; this method is commonly referred to as static fracture-vuggy sculpting. Currently, static fracture-vuggy sculpting (for details, please refer to Li Yang, Theory and Method of Carbonate Rock Fracture-Vuggy Reservoir Development in Tarim Oilfield, Acta Petrolei Sinica, 2013, 34(1):115-121; Zhao Kuanzhi et al., Calculation Method of Fracture-Vuggy Carbonate Oil and Gas Reservoirs in Tarim Basin, Petroleum Exploration and Development, 2015, 42(2):251-256; Li Guohui et al., Quantitative Sculpting Technology of Carbonate Rock Fracture-Vuggy Reservoirs in Halahatang Area of ​​Tarim Basin, China Petroleum Exploration, 2015, 20(4):24-29; Liu Baozeng et al.) Space carving and quantitative description technology of ultra-deep fractured-dissolved reservoirs in Shunbei area, Acta Petrolei Sinica, 2020, 41(4):412-420; Yang Haijun et al., Key technologies for exploration and development of deep fractured-vuggy carbonate condensate gas reservoirs: Taking Tazhong No. 1 gas field in Tarim Basin as an example, Natural Gas Industry, 2020, 40(2):83-89) The general idea is to first use seismic attributes or their fusion to characterize the geometric structure of different fractured-vuggy reservoirs, and then combine the inverted porosity volume to calculate the fractured-vuggy reservoir reserves, so as to obtain a static fractured-vuggy reservoir carving model. Summary of the Invention

[0005] The inventors discovered that current research on fractured-vuggy carbonate reservoirs mainly focuses on the genetic mechanism, with less emphasis on quantitative reservoir characterization. Other studies on fractured-vuggy carbonate reservoirs, while conducting more quantitative characterization studies, primarily rely on static seismic information and extremely limited logging data for fracture-vuggy sculpting, with less research on the constraints and optimization effects of dynamic information in reservoir sculpting. Research indicates that the static fractured-vuggy reservoir sculpting model based on static fracture-vuggy sculpting is actually a comprehensive response of a complex geological body (rock, space, and fluid), not a direct reaction of pore space (see Yang et al., Analysis of Key Factors Affecting Seismic Reflection Characteristics of Karst Fractured-Vuggy Bodies, Petroleum Geophysical Exploration, 2015, 50(3):523-529; Zeng, Characteristics of Deep Seismic Highlights in Ordovician Paleokarst in the Central Part of the Tarim Basin North Uplift, Geophysics, 2011, 76(4):B127-B137; Sa Liming et al.). Seismic response characteristics and identification methods of fractured-vuggy reservoirs, Lithologic Oil and Gas Reservoirs, 2011, 23(1):23-28,73; Xu Chao et al., Fluid identification of carbonate karst cave reservoirs based on seismic physical simulation, Petroleum Geophysical Exploration, 2014, 53(1):116-124; Xiao Pengfei, Application of pre-stack seismic fluid identification technology in carbonate fractured-vuggy reservoirs, Petroleum Geophysical Exploration, 2020, 59(3):450-461); At the same time, static fractured-vuggy carving realized by seismic data and its interpretation methods also has multiple solutions and uncertainties. All of the above factors can cause the static fractured-vuggy reservoir carving model to differ greatly from the actual situation of fractured-vuggy reservoirs in terms of morphology, reserves, and connectivity. This is also the main reason why the current reliance on fractured-vuggy carving leads to low drilling success rate, inaccurate reserve calculation, and unclear connectivity interpretation. In view of the problems existing in related technologies, the purpose of this invention is to make full use of the actual production dynamic data of oil wells, improve the accuracy of fracture and vault carving, and provide a fracture and vault carving method and device for fracture and vault type carbonate reservoirs.

[0006] As one aspect of this invention, a method for fracture-vuggy carbonate reservoir sculpting is provided, comprising:

[0007] Based on the actual production dynamic data of the oil wells obtained, the fractured-vuggy reservoir identification results are determined;

[0008] Based on the fractured-vuggy reservoir identification results and the pre-acquired well data, the seismic impedance inversion is constrained to obtain the impedance volume;

[0009] The static contour volume and average wave impedance value of the constant volume cavern reservoir are obtained by carving the wave impedance body.

[0010] Based on the fractured-vuggy reservoir identification results, the dynamic reserves of the constant-volume cavernous reservoir are calculated.

[0011] Based on the dynamic reserves, static profile volume and average wave impedance of the constant volume cavern reservoir, the average porosity of the constant volume reservoir is calculated, and an equivalent wave impedance-porosity model is established.

[0012] Based on multiple preset porosity thresholds and the wave impedance-porosity equivalent model, multiple cave models and multiple dissolution cavities models are established.

[0013] Based on the pre-acquired seismic attribute information, seismic crack prediction is performed, seismic crack phase model is determined, and the seismic crack phase model is sculpted based on multiple preset seismic parameter threshold values ​​to establish multiple crack models.

[0014] By fusing the multiple crack models, the multiple cave models, and the multiple dissolution cavity models, multiple equally probable crack-cavity reservoir sculpted models are obtained.

[0015] Based on the pre-obtained inter-well connectivity relationships, the multiple equally probable fracture-vuggy reservoir collective carving models are screened to obtain at least one preferred fracture-vuggy reservoir collective carving model.

[0016] In one or more optional embodiments, the fracture-vuggy carbonate reservoir fracture-vuggy carving method further includes:

[0017] Based on the obtained well-controlled dynamic reserves, the at least one preferred fractured-vuggy reservoir sculpting model is screened to obtain the final fractured-vuggy reservoir sculpting model.

[0018] In one or more optional embodiments, the step of screening the at least one preferred fractured-vuggy reservoir collective sculpting model based on the obtained well-controlled dynamic reserves to obtain the final fractured-vuggy reservoir collective sculpting model includes:

[0019] Based on the at least one preferred fractured-vuggy reservoir carving model, fractured-vuggy carving calculations are performed to obtain the static geological reserves of at least one set of fractured-vuggy reservoirs.

[0020] The well-controlled dynamic reserves are calculated based on the preset reservoir engineering method;

[0021] The well-controlled dynamic reserves are matched with the static geological reserves of each group of fractured-vuggy reservoirs to obtain the matching results;

[0022] The preferred fractured-vuggy reservoir sculpting model corresponding to the static geological reserves of the set of fractured-vuggy reservoirs with the highest matching rate in the matching results is determined as the final fractured-vuggy reservoir sculpting model.

[0023] In one or more optional embodiments, determining the fractured-vuggy reservoir identification result based on the acquired actual production dynamic data of the oil well includes:

[0024] Based on the actual production dynamic data of the oil wells, the fractured-vuggy reservoir type and the proportion of each fractured-vuggy reservoir are identified using a preset reservoir dynamic description method. The actual production dynamic data of the oil wells includes one or more of the following: drilling and logging information, acid fracturing modification information, oil testing information, new well testing information, and production testing information.

[0025] In one or more optional embodiments, the seismic impedance inversion is constrained based on the fractured-vuggy reservoir identification results and pre-acquired well data to obtain the impedance volume, including:

[0026] The fractured-vuggy reservoir type and the proportion of each fractured-vuggy reservoir are used as geostatistical information, such as probability density function, proportion relationship or variation function, to constrain the process of seismic impedance inversion based on pre-acquired well data. In addition, the residual calculation of synthetic seismic record and model back-control are performed by combining the seismic volume with the realization of stochastic simulation to obtain the impedance volume.

[0027] In one or more optional embodiments, obtaining the static profile volume and average acoustic impedance value of the constant-volume cavern reservoir based on the acoustic impedance volume sculpting includes:

[0028] Based on the statistical data of abnormal engineering conditions, the longitudinal wave impedance threshold value of the well venting location is obtained, and the upper limit value of the wave impedance of the constant volume cavern reservoir is determined.

[0029] Based on the upper limit of the wave impedance, the wave impedance body is sculpted using a preset three-dimensional sculpting method to depict the spatial shape, static contour volume and average wave impedance value of the wave impedance body.

[0030] In one or more optional embodiments, calculating the dynamic reserves of a constant-volume cavern reservoir based on the fractured-vuggy reservoir identification results includes:

[0031] Based on the fracture-vuggy reservoir type and the proportion of each fracture-vuggy reservoir, the captive-type cavern reservoir group is determined;

[0032] Based on the pre-defined reservoir engineering method, the dynamic reserves of a constant-volume cavernous reservoir were calculated.

[0033] In one or more optional embodiments, the step of calculating the average porosity value of the constant-volume cavern reservoir based on its dynamic reserves, static profile volume, and average acoustic impedance value, and establishing an acoustic impedance-porosity equivalent model, includes:

[0034] The net volume of the constant-volume cavern reservoir is calculated based on the dynamic reserves of the constant-volume cavern reservoir and the pre-obtained fluid density.

[0035] The average porosity value of the constant-volume cavern reservoir is calculated based on the net volume and static profile volume of the constant-volume cavern reservoir.

[0036] Based on the average wave impedance and average porosity of the constant-volume reservoir, an equivalent wave impedance-porosity model is established.

[0037] As another aspect of the present invention, a fracture-cavity carving device for fracture-cavity carbonate reservoirs is provided, comprising:

[0038] The first dynamic processing module is used to determine the fractured-vuggy reservoir identification result based on the actual production dynamic data of the oil wells.

[0039] The wave impedance inversion module is used to constrain the seismic wave impedance inversion based on the fractured-vuggy reservoir identification results and pre-acquired well data to obtain the wave impedance volume.

[0040] The first carving module is used to carve the static contour volume and average wave impedance value of the constant volume cavern reservoir according to the wave impedance body.

[0041] The second dynamic processing module is used to calculate the dynamic reserves of the fixed-volume cavern reservoir based on the fractured-vuggy reservoir identification results.

[0042] The second carving module is used to calculate the average porosity of the constant-volume cavern reservoir based on the dynamic reserves, static profile volume and average wave impedance value of the constant-volume cavern reservoir, and to establish a wave impedance-porosity equivalent model.

[0043] The third carving module is used to establish multiple cave models and multiple dissolution cavity models based on multiple preset porosity threshold values ​​and the wave impedance-porosity equivalent model.

[0044] The fourth carving module is used to predict earthquake cracks based on pre-acquired earthquake attribute information, determine earthquake crack phase models, and carve the earthquake crack phase models based on multiple preset earthquake parameter thresholds to establish multiple crack models.

[0045] The fifth carving module is used to fuse the multiple crack models, the multiple cave models, and the multiple dissolution cavity models to obtain multiple equally probable crack-cavity reservoir carving models.

[0046] The connectivity screening module is used to screen the multiple equally probable fracture-vuggy reservoir collective carving models based on the pre-acquired inter-well connectivity relationships, and obtain at least one preferred fracture-vuggy reservoir collective carving model.

[0047] As a third aspect of the present invention, a computer device is provided, including 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 fracture-cavity carving method for fracture-cavity carbonate reservoirs as described above.

[0048] As a fourth aspect of the present invention, a computer-readable storage medium is provided, the computer-readable storage medium storing a computer program that performs the fracture-cavity carving method for fracture-cavity carbonate reservoirs as described above.

[0049] The beneficial technical effects of this invention are as follows:

[0050] The fracture-vuggy carbonate reservoir fracture-vuggy carving method provided in this invention first fully utilizes the knowledge gained from dynamic analysis and description, and constrains seismic impedance inversion based on the fracture-vuggy reservoir identification results. This reduces the limitations and uncertainties in seismic impedance inversion during the fracture-vuggy carving process caused by insufficient seismic resolution and missing logging curves in fracture and vuggy reservoir development sections, achieving the goal of dynamic and static combined secondary carving. Furthermore, it uses the dynamic reserves of a constant-volume vuggy reservoir and static primary carving to obtain the static contour volume of the constant-volume vuggy reservoir and inversely calculate the porosity. To correct the relationship between wave impedance and porosity in high-porosity regions, an equivalent wave impedance-porosity model was established. This increased the number of data points for the cave development section in the wave impedance-equivalent porosity model, reducing the uncertainty of the equivalent relationship between wave impedance and porosity during static fracture-cavity carving. This allowed for the quantitative characterization of porosity in constant-volume cave-type reservoirs, establishing multiple cave models and multiple dissolution pore models. Furthermore, by dynamically understanding the inter-well connectivity relationship, multiple equally probable fracture-cavity reservoir carving models were screened and optimized to reduce the uncertainty of fractures affecting reservoir connectivity.

[0051] The fracture-vuggy reservoir carving method provided in this invention, based on the identification of key uncertainties affecting the static carving results, including uncertainties in impedance inversion, the relationship between impedance and porosity, and reservoir connectivity, can fully utilize actual production dynamic data. It constrains the fracture-vuggy reservoir carving based on insights gained from dynamic analysis and description, and corrects the static fracture-vuggy reservoir carving model using actual production data. Compared to existing methods that only utilize static seismic information and extremely limited logging data for fracture-vuggy reservoir carving, this method reduces the risk of fracture-vuggy reservoir defects. The uncertainty in the carving process allows for higher precision carving of fractured-vuggy reservoirs, improving the accuracy of the carving results. These results more closely approximate the actual spatial distribution of fractured-vuggy reservoirs in fractured-vuggy carbonate oil reservoirs, meeting actual production needs. This is of great significance for guiding the efficient development of fractured-vuggy carbonate oil and gas reservoirs, and is conducive to further accurately guiding oilfield development and production practices. It provides technical reference for the study of the spatial distribution of reservoirs in this type of fractured-vuggy carbonate oil reservoir, helps improve drilling success rates, and makes the reserve calculation of fractured-vuggy reservoirs more accurate, thus reducing costs and increasing efficiency, and has good economic and social benefits.

[0052] The fracture-vuggy reservoir carving method provided in this invention optimizes the fracture-vuggy reservoir carving model by evaluating the well-controlled dynamic reserves, further reducing the uncertainty in fracture-vuggy reservoir carving, and obtaining a fracture-vuggy reservoir carving model that is closest to the well-controlled dynamic reserves. The final fracture-vuggy reservoir carving model has higher reliability and is more suitable as a basis model for subsequent geological models and numerical simulations, which is beneficial for further guiding oilfield development, production and practice. Attached Figure Description

[0053] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0054] Figure 1a Figure 1 shows the comparison between static sculpted reserves and actual dynamic reserves of fractured-vuggy carbonate reservoirs in a study area.

[0055] Figure 1b Figure 1 shows the comparison between static sculpted reserves and actual dynamic reserves of fractured-vuggy carbonate reservoirs in another study area.

[0056] Figure 2 A comparison of P-wave impedance results from different inversion methods for a seismic profile of a study area;

[0057] Figure 3 A cross-plot of wave impedance and well logging interpretation porosity for a study area;

[0058] Figure 4 shows the crack distribution results of post-stack coherent enhanced crack prediction in a study area;

[0059] Figure 5 A schematic flowchart of the fracture-vuggy carbonate reservoir fracture carving method provided in this embodiment of the invention;

[0060] Figure 6 A flowchart illustrating the fracture-vuggy carbonate reservoir fracture-vuggy carving method provided in this embodiment of the invention. Figure 2 ;

[0061] Figure 7 A flowchart illustrating the fracture-vuggy carbonate reservoir fracture-vuggy carving method provided in this embodiment of the invention. Figure 3 ;

[0062] Figure 8a This is a schematic diagram of the seismic profile through the well.

[0063] Figure 8b This is a schematic diagram of the impedance inversion profile obtained during the exploration phase.

[0064] Figure 8c This is a schematic diagram of the impedance inversion profile of the wellbore during the development phase.

[0065] Figure 8d This is a schematic diagram of the well-wave impedance inversion profile after dynamic constraints during the development phase.

[0066] Figure 9 This is a comparison chart of the wave impedance inversion results based on the static slot carving method and the wave impedance inversion results of the slot carving method provided in the embodiments of the present invention.

[0067] Figure 10 The profile and three-dimensional spatial morphology of the volumetric cavern reservoir in Well-6 are shown.

[0068] Figure 11 This is a cross-plot of wave impedance and porosity after dynamic and static correction.

[0069] Figure 12a A finite fracture-vuggy reservoir sculpting model was selected for the study area H block based on reservoir dynamic description to understand the connectivity of fracture-vuggy reservoirs.

[0070] Figure 12b for Figure 12a The corresponding numerical well test model;

[0071] Figure 13a This is a double logarithmic curve for Well-3 drilling.

[0072] Figure 13b This is a double logarithmic curve for Well-7 drilling.

[0073] Figure 13c This is a double logarithmic curve for drilling well-8;

[0074] Figure 13d This is a flow material balance curve for Well-3.

[0075] Figure 13e This is a flow material balance curve for Well-7 drilling.

[0076] Figure 13f This is a flow material balance curve diagram for Well-8 drilling.

[0077] Figure 14a A connected graph implemented for models where the threshold values ​​for caves, solution cavities, and cracks are all low;

[0078] Figure 14b A connected graph implemented by the model provided in the embodiments of the present invention;

[0079] Figure 14c A connected graph implemented for models with high threshold values ​​for caves, solution cavities, and cracks;

[0080] Figure 15a A diagram showing the relationship between the dynamic fracture-vuggy reservoir volume and the static reservoir volume of fracture-vuggy carvings in Block H.

[0081] Figure 15b This is a schematic diagram of the carving result obtained by the static slot carving method for block H.

[0082] Figure 15c This is a schematic diagram of the engraving result obtained by the slot engraving method provided in the embodiment of the present invention for block H;

[0083] Figure 16 This is a schematic diagram of the fracture-cavity carving device for fracture-cavity carbonate reservoirs provided in an embodiment of the present invention. Detailed Implementation

[0084] 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.

[0085] Exemplary embodiments will now be described in detail, examples of which are illustrated in the accompanying drawings. When the following description relates to the drawings, unless otherwise indicated, the same numerals in different drawings denote the same or similar elements. The embodiments described in the following exemplary embodiments do not represent all embodiments consistent with the present invention. Rather, they are merely examples of apparatuses and methods consistent with some aspects of the invention as detailed in the appended claims.

[0086] In the description of this invention, it should be noted that the terms "center," "upper," "lower," "left," "right," "vertical," "horizontal," "inner," and "outer," etc., indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings. They are used only for the convenience of describing the invention and for simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, or be constructed and operated in a specific orientation. Therefore, they should not be construed as limitations on the invention. Furthermore, the terms "first," "second," and "third" are used for descriptive purposes only and should not be construed as indicating or implying relative importance.

[0087] In the description of this invention, it should be noted that, unless otherwise explicitly specified and limited, the terms "installation," "connection," and "linking" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection; they can refer to a mechanical connection or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium; and they can refer to the internal connection of two components. Those skilled in the art can understand the specific meaning of the above terms in this invention based on the specific circumstances.

[0088] The technical solution of the present invention will be described in detail below through an embodiment of a fracture-vuggy carbonate reservoir fracture-vuggy carving method and apparatus provided by specific implementation methods.

[0089] Example 1

[0090] As the development of fractured-vuggy carbonate reservoirs progresses, the inventors have discovered that while existing static fractured-vuggy sculpting methods can establish geological models reflecting effective reservoir characteristics, quantitatively characterizing the spatial distribution, morphological combinations, and connectivity of fractured-vuggy reservoirs, providing a basis for reservoir prediction, reserve evaluation, drilling and completion, and adjustments to development measures, static fractured-vuggy sculpted bodies are actually a comprehensive response of a complex geological body (rock, space, and fluids), not a direct reflection of pore space. Furthermore, single seismic interpretation methods also suffer from ambiguity and uncertainty. These factors can cause significant discrepancies between the static sculpted bodies and actual conditions in terms of morphology, reserves, and connectivity. This leads to problems such as low drilling success rates, inaccurate reserve calculations, and unclear connectivity interpretations when relying on static fractured-vuggy sculpting to guide oilfield development and production.

[0091] The inventors discovered that traditional static fracture-cavity carving mainly relies on seismic data to depict fracture-cavity reservoirs (see Liu Qun et al., Quantitative Calculation of Fracture-Cavity Volume in Carbonate Rocks and Analysis of Influencing Factors: A Case Study of the Main Area of ​​Tahe Oilfield, Petroleum Geophysical Exploration, 2013, 52(2):217-222; Peng Gengxin et al., Seismic Exploration and Fracture-Cavity Carving Technology of Ultra-Deep-Sea Carbonate Rocks, Beijing: Petroleum Industry Press, 2017), which involves significant uncertainties. (Refer to...) Figure 1a and Figure 1b As shown in the figure, the comparison results between the static sculpted reserves and the actual dynamic reserves of fractured-vuggy carbonate reservoirs obtained from the static fractured-vuggy sculpting model are shown. These uncertainties are manifested in the fact that the sculpting features such as fractured-vuggy morphology, reserve scale, and connectivity between fractured-vuggy bodies are greatly affected by seismic interpretation methods and parameter settings, resulting in a large difference between the static sculpted reserves and the dynamic evaluation reserves, while the dynamic reserves represent the actual reserves of the reservoir.

[0092] In reality, the statically sculpted reserves obtained from the static fracture-vuggy reservoir model differ significantly from the actual reservoir reserves. This is partly due to insufficient seismic resolution caused by the deep burial depth of fracture-vuggy reservoirs and surface acquisition factors, but more importantly, it is due to the superposition of multiple uncertain influencing factors during data application and interpretation. Given a certain level of data quality, it is crucial to strengthen research on these uncertainties and their impact to reduce uncertainty and make the reservoir sculpting results closer to the actual underground situation.

[0093] The inventors of this invention studied the uncertainties in the carving of seams and holes caused by existing static seam carving methods, and found that the uncertainties in static seam carving methods are mainly manifested as follows:

[0094] (1) Limitations and uncertainties of earthquake inversion

[0095] Seismic impedance inversion is a fundamental method for characterizing the distribution of fractured cavities. Currently, inversion methods include deterministic inversion and statistical inversion. Deterministic inversion lacks sufficient logging information constraints and is completely faithful to seismic data, resulting in significant uncertainty in the inversion results. Furthermore, when large cavernous reservoirs are developed in carbonate strata, they exhibit strong reflections on seismic profiles, severely weakening the reflections of connected or adjacent small pore-type reservoirs, making them unsuitable for proper characterization.

[0096] Statistical inversion, by providing prior probabilities for different reservoir types, probability density functions, and vertical and horizontal variability functions, generates multiple equally probable acoustic impedance simulation results using Bayesian discriminant analysis and Monte Carlo simulation. When the residual between the forward-modeled seismic data and the actual seismic data obtained from the simulation is less than a set value, the geostatistical model and the seismic model can be considered to be basically consistent. Statistical inversion offers high resolution and can describe the internal structure of fractured-cavitary reservoirs, especially porous layers. However, when static data such as drilling, logging, and well logging are insufficient, the prior probability uncertainty of cave-type reservoirs, porous reservoirs, and tight limestone layers within a certain interval is relatively large. (Refer to...) Figure 2 The seismic profile shown and the comparison results of P-wave impedance results of different inversion methods are presented. Among the four implementation results, each implementation result conforms to the lithofacies proportion (cavity layer, porous layer, dense layer), probability density function, etc. given by statistical parameters. The statistics simulate different combinations of lithofacies types in the vertical direction. Therefore, the impedance model generated by the uncertainty of inversion also has uncertainty.

[0097] (2) Uncertainty in porosity prediction

[0098] Seismic impedance is a comprehensive reflection of the rock, reservoir space, and fluid within fractured-vuggy reservoirs, and it has a good positive correlation with porosity (reservoir space). Current methods primarily establish an equivalent relationship between seismic impedance and logging porosity, then convert the seismic impedance into reservoir porosity using linear or nonlinear methods. However, for fractured-vuggy reservoirs, logging only measures relatively small-scale pores and porous reservoirs, while cavernous reservoirs, which contribute the most to reservoir space, lack logging information. This directly leads to the inability of impedance-porosity conversion models to fully characterize the characteristics of fractured-vuggy carbonate reservoirs, resulting in significant errors and uncertainties in the final results. Through statistical analysis of actual well data from the Tarim fractured-vuggy carbonate reservoir, optimistic, expected, and pessimistic models of porosity and P-wave impedance values ​​are determined, referencing… Figure 3 As shown, a cross-plot of well logging interpretation porosity and P-wave impedance values ​​is established. Figure 3 It can be observed that the porosity interpreted by well logging is less than 8%. Within this range, porosity and P-wave impedance have a certain correlation, but there is also a certain degree of uncertainty. The maximum and minimum porosity values ​​under the same wave impedance differ by about 3-4%. More seriously, for high-quality reservoir sections with porosity greater than 8% and larger cave-type reservoirs, quantification is impossible due to the lack of effective well logging curves.

[0099] (3) Uncertainty in reservoir connectivity characterization

[0100] Fractured-vuggy carbonate reservoirs exhibit highly complex connectivity due to the development of pores and fractures at different scales. Fractures can improve the physical properties of carbonate reservoirs and also serve to connect reservoirs, directly impacting reservoir connectivity and reservoir size. Larger-scale fractures can cause changes in seismic response. Currently, fractures are mainly identified using a combination of seismic attributes such as coherence volume, ant volume, and curvature volume (see Wang Shuyu et al., Application of Multi-Attribute Clustering Method Based on Principal Component Analysis in Fracture Prediction, Oil & Gas Geophysics, 2019, 17(1):60-62,67). However, due to limited seismic resolution, significant differences in the characterization results of different seismic attributes, and the complex distribution of fractures at different scales, fracture prediction results have very high uncertainty. Seismic attribute-based fracture sculpting is a statistical pattern recognition method, and the sculpting results heavily depend on the quality of the wellbore fracture model. The difficulty in obtaining logging curves for fracture-vuggy development zones results in insufficient or unrepresentative well samples, leading to significant uncertainty in fracture distribution prediction results. Meanwhile, selecting a threshold value that is too high or too low for the interpretation of cracks based on seismic attributes can also lead to large differences in crack carving results (for details, please refer to Deng Xiaojuan et al., Uncertainty Modeling Method for Multi-Scale Fractured-Vuggy Carbonate Reservoirs, Acta Petrolei Sinica, 2018, 39(9):1051-1062). Figure 4a and 4b As shown, by conducting post-stack coherent enhanced fracture prediction on the Yijianfang Formation of Halahatang in Tarim Oilfield, the fracture distribution when the similarity is less than 0.65 and 0.7 is displayed, indicating that these two fracture distribution patterns directly affect the judgment of fracture-cavity connectivity and scale.

[0101] In order to at least partially solve the aforementioned uncertainty problems discovered by the inventors, the inventors made this invention. The inventors proposed a fracture and cavity carving method that clearly defines three main uncertainty parameters in the fracture and cavity carving process: wave impedance inversion, wave impedance-porosity relationship, and reservoir connectivity, as well as a "secondary carving" method that considers uncertainty. The method achieves quantitative and accurate carving of fractures and cavities by combining dynamic data from actual production with static fracture and cavity carving methods.

[0102] In this embodiment of the invention, the method of depicting the fracture-cavity body using static seismic data and extremely limited logging information can be called static fracture-cavity carving or "primary carving". On the basis of static carving, the carving body is corrected again by supplementing and understanding other data, especially large-scale production dynamic data, new means and new methods, which can be called "secondary carving" (or "secondary quantitative carving").

[0103] During the development phase, oilfields accumulate abundant dynamic data, including various types of dynamic data such as production volume, injection volume, pressure monitoring, well testing, and oil testing. By combining the insights and results obtained from the analysis of dynamic production data with static sculpting, the deficiencies and inadequacies in core and logging data of fractured-vuggy reservoirs can be compensated for. This significantly reduces uncertainties in the fracture-vuggy sculpting process caused by insufficient seismic resolution and missing logging curves in fractured and cavernous reservoir development sections. For example, dynamic information can be used to constrain seismic impedance inversion, reservoir porosity can be calculated from dynamic reserves to correct static sculpted porosity, the oil-water interface can be inferred using dynamic methods, reservoir connectivity can be evaluated through dynamic response, and fracture-vuggy sculpting models can be corrected through numerical simulation. This allows for a combined dynamic and static quantitative characterization of the type, scale, connectivity, physical properties, other reservoir characteristics, and parameters of fractured-vuggy carbonate reservoirs, achieving "secondary quantitative sculpting" of fractured-vuggy reservoirs. The combination of dynamic and static methods is the core of the "secondary quantitative sculpting" concept.

[0104] Reference Figure 5 As shown in the embodiment of the present invention, a method for fracturing and caving a fractured-cavity carbonate reservoir includes the following steps:

[0105] S101: Based on the actual production dynamic data of the oil wells obtained, determine the fractured-vuggy reservoir identification results;

[0106] S102: Based on the fractured-vuggy reservoir identification results and the pre-acquired well data, the seismic impedance inversion is constrained to obtain the impedance volume;

[0107] S103: Obtain the static contour volume and average wave impedance value of the constant volume cavern reservoir by carving the wave impedance body.

[0108] S104: Based on the fractured-vuggy reservoir identification results, the dynamic reserves of the constant-volume cavernous reservoir are calculated;

[0109] S105: Based on the dynamic reserves, static profile volume and average wave impedance value of the constant volume cavern reservoir, calculate the average porosity value of the constant volume reservoir and establish a wave impedance-porosity equivalent model.

[0110] S106: Based on multiple preset porosity thresholds and the wave impedance-porosity equivalent model, establish multiple cave models and multiple dissolution cavities models;

[0111] S107: Based on the pre-acquired seismic attribute information, predict seismic cracks, determine the seismic crack phase model, and sculpt the seismic crack phase model based on multiple preset seismic parameter thresholds to establish multiple crack models.

[0112] S108: The multiple crack models, multiple cave models and multiple dissolution cavity models are fused to obtain multiple equally probable crack-cavity reservoir carving models;

[0113] S109: Based on the pre-obtained inter-well connectivity relationship, the multiple equally probable fracture-vuggy reservoir collective carving models are screened to obtain at least one preferred fracture-vuggy reservoir collective carving model.

[0114] In one embodiment, the fracture-cavity carving method for fractured-cavity carbonate reservoirs described above refers to... Figure 6 As shown, it also includes the following steps:

[0115] S110: Based on the obtained well-controlled dynamic reserves, the at least one preferred fractured-vuggy reservoir collective carving model is screened to obtain the final fractured-vuggy reservoir collective carving model.

[0116] In one specific embodiment, step S110 above, which involves screening the at least one preferred fractured-vuggy reservoir collective sculpting model based on the obtained well-controlled dynamic reserves to obtain the final fractured-vuggy reservoir collective sculpting model, specifically includes:

[0117] Based on the at least one preferred fractured-vuggy reservoir carving model, fractured-vuggy carving calculations are performed to obtain the static geological reserves of at least one set of fractured-vuggy reservoirs.

[0118] The well-controlled dynamic reserves are calculated based on the preset reservoir engineering method;

[0119] The well-controlled dynamic reserves are matched with the static geological reserves of each group of fractured-vuggy reservoirs to obtain the matching results;

[0120] The preferred fractured-vuggy reservoir sculpting model corresponding to the static geological reserves of the set of fractured-vuggy reservoirs with the highest matching rate in the matching results is determined as the final fractured-vuggy reservoir sculpting model.

[0121] In this embodiment of the invention, the above-mentioned preset reservoir engineering method can be based on the production instability analysis method or the material balance method, or it can be implemented by selecting other reservoir engineering methods in the prior art according to actual needs. The specific implementation process can be referred to the detailed description in the prior art, and will not be repeated here.

[0122] In this embodiment of the invention, when the well-controlled dynamic reserves are matched with the static geological reserves of each group of fractured-vuggy reservoirs to obtain the matching results, for fixed-volume cave-fractured bodies, where production wells are isolated and less affected by water, the calculated dynamic reserves are more reliable and can be used as reliable well hard data to optimize the static fractured-vuggy carving results; for fractured, fracture-vuggy, and fracture-pore reservoirs that are more affected by water, the calculated dynamic reserves are less reliable and are used as reference well soft data to optimize the fractured-vuggy carving results.

[0123] In this embodiment of the invention, the fractured-vuggy reservoir sculpting model is ultimately optimized using the well-controlled dynamic reserve evaluation results. The higher the consistency rate between the fractured-vuggy reservoir sculpting model and the evaluated well-controlled dynamic reserves, the more reliable the model. By comparing the static geological reserves of the reservoir calculated by the fractured-vuggy reservoir sculpting model with the dynamic reserves calculated by reservoir engineering methods, the fractured-vuggy reservoir sculpting model that is closest to the dynamic reserves is selected as the basis model for subsequent geological models and numerical simulations, thereby further guiding oilfield development, production, and practice.

[0124] In one specific embodiment, step S101 above, which determines the fractured-vuggy reservoir identification result based on the acquired actual production dynamic data of the oil well, specifically includes:

[0125] Based on the actual production dynamic data of the oil wells, the fractured-vuggy reservoir type and the proportion of each fractured-vuggy reservoir are identified using a preset reservoir dynamic description method. The actual production dynamic data of the oil wells includes one or more of the following: drilling and logging information, acid fracturing modification information, oil testing information, new well testing information, and production testing information.

[0126] In this embodiment of the invention, the fractured-vuggy reservoir type and the proportion of each type of fractured-vuggy reservoir can be comprehensively identified by using dynamic information from actual oil well production data, including drilling and logging, acid fracturing, oil testing, well testing, and production testing, as well as reservoir dynamic description technology. For example, after the oilfield enters the development stage, the reservoir type in the well area can be comprehensively classified into two categories—cavitary and fractured-vuggy—using a large amount of new dynamic data from drilling and logging, acid fracturing, oil testing, well testing, and production testing, and the proportion of the two types of reservoirs can be statistically obtained.

[0127] In one specific embodiment, step S102 above, constraining the seismic impedance inversion based on the fractured-vuggy reservoir identification results and pre-acquired well data to obtain the impedance volume, specifically includes:

[0128] The fractured-vuggy reservoir type and the proportion of each fractured-vuggy reservoir are used as geostatistical information, such as probability density function, proportion relationship or variation function, to constrain the process of seismic impedance inversion based on pre-acquired well data. In addition, the residual calculation of synthetic seismic record and model back-control are performed by combining the seismic volume with the realization of stochastic simulation to obtain the impedance volume.

[0129] In this embodiment of the invention, dynamic reservoir knowledge is used as geostatistical information such as probability density function, proportion relationship, and variation function to constrain seismic impedance inversion. Combined with the realization of random simulation of seismic bodies, the residual of synthetic seismic record is calculated and the model is controlled back, thereby reducing the uncertainty in impedance inversion and achieving the purpose of dynamic and static "secondary carving".

[0130] In one specific embodiment, step S103 above, which involves obtaining the static contour volume and average acoustic impedance value of a constant-volume cavern reservoir based on the acoustic impedance volume carving, includes:

[0131] Based on the statistical data of abnormal engineering conditions, the longitudinal wave impedance threshold value of the well venting location is obtained, and the upper limit value of the wave impedance of the constant volume cavern reservoir is determined.

[0132] Based on the upper limit of the wave impedance, the wave impedance body is sculpted using a preset three-dimensional sculpting method to depict the spatial shape, static contour volume and average wave impedance value of the wave impedance body.

[0133] In one specific embodiment, step S104 above, which involves calculating the dynamic reserves of a constant-volume cavern reservoir based on the fractured-vuggy reservoir identification results, includes:

[0134] Based on the fracture-vuggy reservoir type and the proportion of each fracture-vuggy reservoir, the captive-type cavern reservoir group is determined;

[0135] Based on the pre-defined reservoir engineering method, the dynamic reserves of a constant-volume cavernous reservoir were calculated.

[0136] In one specific embodiment, in step S105 above, based on the dynamic reserves, static profile volume, and average wave impedance value of the constant-volume cavern reservoir, the average porosity value of the constant-volume reservoir is calculated, and a wave impedance-porosity equivalent model is established, including:

[0137] The net volume of the constant-volume cavern reservoir is calculated based on the dynamic reserves of the constant-volume cavern reservoir and the pre-obtained fluid density.

[0138] The average porosity value of the constant-volume cavern reservoir is calculated based on the net volume and static profile volume of the constant-volume cavern reservoir.

[0139] Based on the average wave impedance and average porosity of the constant-volume reservoir, an equivalent wave impedance-porosity model is established.

[0140] In this embodiment of the invention, the dynamic reserves of wells already in production are evaluated using methods such as production instability analysis and material balance. The dynamic reserves of caverns are combined with the static profile volume to inversely estimate the average porosity of the constant-volume cavernous reservoir, thereby correcting the relationship between wave impedance and porosity in the high-porosity range. This increases the number of data points in the cavernous development section of the wave impedance-porosity equivalent model, making up for the large uncertainty of porosity obtained by the empirical assignment method, and thus quantitatively characterizing the porosity of cavernous reservoirs.

[0141] In this embodiment of the invention, in step 106 above, the longitudinal wave impedance distribution range of each type of reservoir can be obtained by statistically analyzing the proportion of each type of reservoir in the study area. Then, the preset multiple porosity threshold values ​​can be determined based on the longitudinal wave impedance distribution range of each type of reservoir. The specific implementation method can be referred to in the detailed description in the prior art, and no specific limitation is required here.

[0142] In this embodiment of the invention, when predicting earthquake cracks in step 107 based on the pre-acquired earthquake attribute information, the method of comprehensively identifying cracks using earthquake attributes such as coherence volume, ant volume, and curvature volume as described in the prior art can be adopted. The specific implementation process can be referred to the detailed description in the prior art, and no specific limitation is made here.

[0143] In this embodiment of the invention, the fusion method for fusing the plurality of crack models, the plurality of cave models and the plurality of dissolution cavity models in step 108 above can adopt a fusion algorithm in the prior art, such as the same position condition assignment algorithm. The specific implementation process of the fusion algorithm can be referred to the detailed description in the prior art, and will not be repeated here.

[0144] In this embodiment of the invention, in step 109 above, well connectivity can be determined by direct detection methods (e.g., chemical tracer detection), by production dynamic analysis methods such as injection-production response, pressure response, and production instability analysis, and / or by rapidly and quantitatively evaluating well connectivity based on production information and CRM models. Specifically, well connectivity can be directly understood through monitoring methods such as tracer testing, inter-well microseismic testing, and interference well testing. Well connectivity can also be identified through production dynamic analysis methods such as injection-production response, pressure response, and production instability analysis. Furthermore, actual injection-production data can be fully utilized to rapidly and quantitatively evaluate well connectivity. Existing models include multiple regression models, capacitance models, multi-well production indices, and flow network models. Among these, the capacitance model (CRM) is an injection rate time-delay model derived from the principles of hydroelectric similarity and mass balance. It characterizes reservoir production data changes through connectivity coefficients, time-delay constants, and production indices, thereby achieving a quantitative characterization of connectivity.

[0145] After determining the inter-well connectivity, the fractured-vuggy-reservoir collective sculpting model is then optimized based on the inter-well connectivity. That is, from the multiple fractured-vuggy-reservoir collective sculpting models established after considering the impact of uncertainty and the participation of dynamic information to reduce the impact of uncertainty, the model that is consistent with the understanding of inter-well connectivity in dynamic analysis is selected.

[0146] The fracture-vuggy carbonate reservoir fracture-vuggy carving method provided in this invention first fully utilizes the knowledge gained from dynamic analysis and description, and constrains seismic impedance inversion based on the fracture-vuggy reservoir identification results. This reduces the limitations and uncertainties in seismic impedance inversion during the fracture-vuggy carving process caused by insufficient seismic resolution and missing logging curves in fracture and vuggy reservoir development sections, achieving the goal of dynamic and static combined secondary carving. Furthermore, it uses the dynamic reserves of a constant-volume vuggy reservoir and static primary carving to obtain the static contour volume of the constant-volume vuggy reservoir and inversely calculate the porosity. To correct the relationship between wave impedance and porosity in high-porosity regions, an equivalent wave impedance-porosity model was established. This increased the number of data points for the cave development section in the wave impedance-equivalent porosity model, reducing the uncertainty of the equivalent relationship between wave impedance and porosity during static fracture-cavity carving. This allowed for the quantitative characterization of porosity in constant-volume cave-type reservoirs, establishing multiple cave models and multiple dissolution pore models. Furthermore, by dynamically understanding the inter-well connectivity relationship, multiple equally probable fracture-cavity reservoir carving models were screened and optimized to reduce the uncertainty of fractures affecting reservoir connectivity.

[0147] The fracture-vuggy reservoir carving method provided in this invention, based on the identification of key uncertainties affecting the static carving results, including uncertainties in impedance inversion, the relationship between impedance and porosity, and reservoir connectivity, can fully utilize actual production dynamic data. It constrains the fracture-vuggy reservoir carving based on insights gained from dynamic analysis and description, and corrects the static fracture-vuggy reservoir carving model using actual production data. Compared to existing methods that only utilize static seismic information and extremely limited logging data for fracture-vuggy reservoir carving, this method reduces the risk of fracture-vuggy reservoir defects. The uncertainty in the carving process allows for higher precision carving of fractured-vuggy reservoirs, improving the accuracy of the carving results. These results more closely approximate the actual spatial distribution of fractured-vuggy reservoirs in fractured-vuggy carbonate oil reservoirs, meeting actual production needs. This is of great significance for guiding the efficient development of fractured-vuggy carbonate oil and gas reservoirs, and is conducive to further accurately guiding oilfield development and production practices. It provides technical reference for the study of the spatial distribution of reservoirs in this type of fractured-vuggy carbonate oil reservoir, helps improve drilling success rates, and makes the reserve calculation of fractured-vuggy reservoirs more accurate, thus reducing costs and increasing efficiency, and has good economic and social benefits.

[0148] The fracture-vuggy reservoir carving method provided in this invention optimizes the fracture-vuggy reservoir carving model by evaluating the well-controlled dynamic reserves, further reducing the uncertainty in fracture-vuggy reservoir carving, and obtaining a fracture-vuggy reservoir carving model that is closest to the well-controlled dynamic reserves. The final fracture-vuggy reservoir carving model has higher reliability and is more suitable as a basis model for subsequent geological models and numerical simulations, which is beneficial for further guiding oilfield development, production and practice.

[0149] The following is a detailed explanation of the fracture-vuggy carbonate reservoir sculpting method provided in this invention through a specific application example:

[0150] The Ordovician carbonate rocks in the Tarim Basin are old, deeply buried, and large in scale, having undergone multiple tectonic movements and karstification. This has resulted in a lack of facies control in clastic reservoirs, characterized by the development of dissolution pores, fractures, and caves, exhibiting strong heterogeneity. During drilling, engineering anomalies such as "venting" or "leakage" frequently occur in fracture-vuggy sections, making it impossible to obtain effective core and logging data. Consequently, domestic development of such reservoirs primarily employs the static fracture-vuggy sculpting method, relying solely on static seismic information and extremely limited logging data. However, a static fracture-vuggy sculpted body is actually a comprehensive response of a complex geological body (rock, space, and fluids), not a direct reflection of pore space. Furthermore, seismic data and its interpretation methods are subject to ambiguity and uncertainty. These factors contribute to significant discrepancies between the understanding of the morphology, reserves, and connectivity of static sculpted bodies and the actual situation, which is a major reason for the current low drilling success rate of fracture-vuggy reservoirs.

[0151] To address the shortcomings of static fracture-vuggy carbonate reservoir carving methods, this invention innovatively employs a secondary quantitative carving technique that combines static and dynamic approaches to consider uncertainties, providing a technical reference for the study of reservoir spatial distribution in this type of reservoir. Taking the Ordovician fracture-vuggy carbonate reservoir in Block H of the Halahatang reservoir in the Tarim Oilfield as an example, the concept and technical method of "secondary carving" of fracture-vuggy reservoirs are proposed. Based on the analysis of key uncertainty factors in static fracture-vuggy carving, the static fracture-vuggy carved body is corrected through a combination of static and dynamic methods. This improves the accuracy of acoustic impedance inversion and porosity interpretation, dynamically evaluates the connectivity of the fracture-vuggy body, and optimizes the fracture-vuggy reservoir carving model, thereby reducing uncertainties in the fracture-vuggy carving process. This is of great significance for guiding the efficient development of fracture-vuggy carbonate oil and gas reservoirs. This method was applied to the development of the Halahatang fractured-cavity carbonate reservoir in the Tarim Oilfield, effectively guiding the deployment of 42 new wells and 38 wells with a production capacity of 100 tons per day. The drilling success rate increased from 74% to 95%, the proportion of high-efficiency wells increased from 28% to 65%, and the daily oil production of new wells increased from 35 tons to 74 tons, resulting in a new production capacity of 660,000 tons. It has been proven to effectively improve the accuracy of fractured-cavity characterization by 20%, and has strongly consolidated the geological foundation of the oilfield.

[0152] In this embodiment of the invention, the fracture-vuggy carbonate reservoir fracture-vuggy carving method, namely the "secondary carving" technology, is based on fully utilizing the knowledge gained from dynamic analysis and dynamic description to reduce the uncertainties in the fracture-vuggy carving process caused by insufficient seismic resolution and missing logging curves in fracture and vuggy reservoir development sections. The specific process is as follows: Figure 7 . Reference Figure 7As shown, based on static fracture-vuggy sculpting, this study focuses on three main uncertainties in the process: impedance inversion, impedance-porosity relationship, and reservoir connectivity. By utilizing dynamic information from drilling and logging, acid fracturing, oil testing, well testing, and production testing, along with reservoir dynamic description techniques, the study comprehensively identifies fracture-vuggy reservoir types and their proportions. Dynamic reservoir understanding is used as geostatistical information such as probability density functions, proportion relationships, and variation functions to constrain impedance inversion. Furthermore, combined with the implementation of stochastic simulations using seismic bodies, the study calculates synthetic seismic record residuals and performs model back-control, ultimately reducing uncertainties in impedance inversion and achieving the goal of dynamic-static combined secondary sculpting. The dynamic reserves of producing wells are evaluated using methods such as production instability analysis and material balance. The dynamic reserves of caverns are combined with the static sculpted volume to inversely estimate the average porosity of constant-volume cavernous reservoirs, thereby correcting the relationship between wave impedance and porosity in high-porosity regions. This increases the number of data points in the cavernous development section of the wave impedance-equivalent porosity model, compensating for the high uncertainty of porosity obtained by empirical assignment methods, and thus quantitatively characterizing the porosity of cavernous reservoirs. Production dynamic analysis methods such as injection-production response, pressure response, and production instability analysis, along with rapid quantitative evaluation of well connectivity based on production information and CRM models, are used to quickly and quantitatively evaluate inter-well connectivity. The reservoir connectivity determined by dynamic analysis is used to optimize the fracture-cavity sculpting model; that is, from multiple fracture-cavity reservoir sculpting results established after considering the impact of uncertainty and the participation of dynamic information to reduce uncertainty, the model consistent with the connectivity understanding of dynamic analysis is selected. To further reduce the uncertainty in fracture-cavity sculpting, the dynamic reserve evaluation results are used for the final optimization of the fracture-cavity reservoir model; the higher the consistency rate with the evaluated dynamic reserves, the more reliable the static fracture-cavity sculpting model. By comparing the static geological reserves of reservoirs calculated using fracture-vuggy carving with the dynamic reserves calculated using reservoir engineering methods, a fracture-vuggy carving model that closely approximates the dynamic reserves is selected as the foundation model for subsequent geological models and numerical simulations, thereby further guiding oilfield development and production practices. Combining dynamic and static analyses ensures consistency between them, resulting in more reliable carving results. Application of this method in Block H demonstrates a significant improvement in the accuracy of fracture-vuggy carving results, with a higher degree of agreement with reservoir characteristics revealed by production.

[0153] The following is a detailed description of the specific process of implementing the fracture-vuggy sculpting method for Ordovician fracture-vuggy carbonate reservoirs in Block H of the Halahatang oilfield in the Tarim Oilfield:

[0154] (1) Geostatistical impedance inversion with dynamic data constraints

[0155] Geostatistical inversion is an organic combination of traditional well-based geological modeling and seismic inversion techniques. It is a high-resolution reservoir prediction method that fully integrates well logging, seismic, and geostatistical information. When relying solely on well logging curves to constrain inversion results in significant uncertainty, dynamic information from drilling and logging, acid fracturing, well testing, and production testing, along with dynamic reservoir description techniques, can be used to comprehensively identify fractured-vuggy reservoir types and their proportions. Dynamic reservoir understanding is used as a constraint for impedance inversion based on geostatistical information such as probability density functions, proportions, and variogram functions. Combined with the implementation of stochastic simulations of seismic volumes, synthetic seismic record residual calculations and model back-control are performed, ultimately reducing the uncertainty in impedance inversion and achieving a dynamic-static combined secondary modeling effect.

[0156] Reference Figure 8a As shown, the H block had relatively few wells drilled during the exploration phase, only well-1 and well-3, and the targets were mainly cave-type reservoirs with strong amplitude beaded reflections. Venting often occurred when drilling reached the top of the strong beaded formation. This phase primarily used deterministic inversion techniques faithful to seismic resolution for static fracture-cavity sculpting, and the sculpting results are shown below. Figure 8b As shown, due to the limitations of seismic resolution, this technique only reflects cave-type reservoirs with larger porosity and stronger reflection amplitude, but does not reflect the possible presence of pore-type reservoirs with smaller porosity that are difficult to distinguish on seismic data.

[0157] In addition, there are no well logging curves for the target layer, so the approximate shape and volume of the cave reservoir can only be obtained by seismic inversion, which cannot quantitatively characterize the size of the cave space.

[0158] After entering the development phase, the number of wells drilled increased, referring to... Figure 8c As shown, wells 2, 4, 5, and 6 were newly added, revealing the existence of fracture-porosity reservoirs in non-strong seismic reflection zones adjacent to cave-type reservoirs. Based on the proportion of each reservoir type revealed by drilling, the P-wave impedance distribution ranges of tight limestone, fracture-porosity limestone, and cave reservoirs were statistically analyzed: the P-wave impedance ranges of tight limestone and porous limestone can be calculated from well logging. The statistical lower limit of porosity for porous reservoirs in the study area is 2%, corresponding to a mean P-wave impedance of 1.6 × 10⁷ kg / m². 3 *m / s, with an upper limit porosity of 6%, corresponding to a mean wave impedance of 1.45×10⁷ kg / m 3 *m / s; Cave-type reservoirs lack well logging curves; their acoustic impedance distribution range is mainly obtained from seismic deterministic inversion statistics, with a mean of 1.3×10⁷ kg / m 3 *m / s.

[0159] Reference Figure 8cAs shown, the above methods increase the proportion of porous reservoirs in statistical inversion, making the sculpting results closer to the actual reservoir distribution. However, the sculpting of fractured-vuggy reservoirs at this development stage still mainly relies on static data such as seismic, logging, drilling, and well logging. For porous reservoirs, sculpting is mainly done by establishing equivalent relationships between logging and wave impedance to calculate porosity and reservoir size, while it is still difficult to quantitatively sculpt cavernous reservoirs.

[0160] As the research area development deepened and dynamic information increased, reservoir engineers found that the production status of individual wells, well test analysis results, and reservoir types, scales, and connectivity identified by static sculpting were difficult to match. For example, through analysis of well test data and dynamic production data such as changes in production volume and pressure, it was concluded that well-2 and well-4 mainly exhibited porous reservoir characteristics, while well-1, well-3, well-5, and well-6 mainly exhibited cavernous and porous reservoir fluid supply in the early stages of production and porous reservoir fluid supply in the later stages. Furthermore, the reserves calculated dynamically were significantly smaller than the reserves identified in the initial static sculpting.

[0161] Because static fracture-vuggy engraving is affected by strong heterogeneity, reservoir sections experience venting and leakage. The ratio of porosity to cavernous reservoirs revealed by drilling, logging, and well logging is not representative, leading to unreasonable statistical parameters. Overall, the proportion of porosity-type reservoirs is underestimated, while the proportion of cavernous reservoirs and tight layers is overestimated. Based on this, referring to... Figures 8a-8d As shown, based on the understanding of reservoir type, scale, and lateral variation in dynamic description, statistical parameters such as reservoir proportion, lateral range, and vertical variation were optimized to constrain geostatistical impedance inversion. (Refer to...) Figure 8b , Figure 8c and Figure 8d The comparison revealed that, Figure 8d The inversion results shown indicate that the porosity of the reservoir is at a medium to low impedance ratio. Figure 8b and Figure 8c The inversion results shown have more distributions. Figure 8d The inversion results shown indicate that well-2 and well-4, drilled during the development phase, are both porous reservoirs, and the fractured-vuggy system exhibits better connectivity. The production dynamics of well-4 and well-5 show that they are interconnected well groups, which is consistent with the understanding of production characteristics and dynamic descriptions.

[0162] Furthermore, refer to Figure 9 As shown, due to the limited number of wells drilled during the exploration phase, there was a lack of understanding of reservoir distribution and the proportion of different reservoir types. This led to biases in the initial statistical inversion parameters. Later drilling revealed inversion results that did not match the reservoir characteristics reflected in actual production, indicating that the fracture-vuggy sculpting results based on early inversion results could no longer meet the needs of development adjustments. After entering the development phase, [further details are needed]. Figure 9As shown, by comprehensively analyzing a large amount of new dynamic data from drilling and logging, acid fracturing, oil testing, well testing, and production testing, the reservoir types in this well area were classified into two categories: cavernous and fractured-vuggy. The proportion of the two types of reservoirs was also statistically analyzed. The reservoir understanding obtained through dynamic analysis was used to readjust statistical parameters such as the ratio of reservoirs to non-reservoirs and the proportion of each type of reservoir, which were then used to constrain geostatistical impedance inversion. The inversion results showed a higher degree of agreement with the drilling data.

[0163] (2) Dynamic and static combined correction of porosity and wave impedance relationship

[0164] For fractured-vuggy carbonate reservoirs, drilling and logging data cannot be effectively obtained from fractured-vuggy sections. When performing static fracture-vuggy sculpting, refer to... Figure 3 As shown, due to the lack of data for the cave development section (low to medium wave impedance and porosity greater than 8%) in the wave impedance-equivalent porosity model, the prediction results using the empirical assignment method have very high uncertainty. For this type of constant-volume cave-type reservoir, the dynamic reservoir volume calculated by reservoir engineering methods has high reliability. Therefore, by combining the dynamic cave reserve with the static sculpted volume, the average porosity of the constant-volume cave-type reservoir is inferred, thereby increasing the data points for the cave development section in the wave impedance-porosity equivalent model. This compensates for the high uncertainty of porosity obtained by the empirical assignment method, and thus quantitatively characterizes the porosity of cave-type reservoirs.

[0165] Reference Figure 10 As shown, taking Well-6 as an example, after drilling to a depth of 3m, it was identified as a constant-volume cavernous reservoir based on production dynamics analysis. This type of fractured-cavitary structure exhibits a "beaded" reflection pattern on seismic profiles. These production wells are essentially water-free during production, and the reservoir is minimally affected by water bodies. Therefore, the dynamic reserves calculated using the production instability analysis method are reliable. Based on engineering anomalies, the P-wave impedance threshold at the well venting location in the study area can be statistically determined, thus establishing the upper limit of the wave impedance for cavernous reservoirs. Then, 3D sculpting technology is used to depict the spatial morphology, volume, and average P-wave impedance of the cavernous reservoir. The volume of the cavernous reservoir space under formation conditions is calculated based on the dynamic reserves and fluid density. Finally, combined with the static sculpted volume, the average porosity of the cavernous reservoir can be calculated. This reliable dynamic reserve data can be used to calculate the average porosity of the caverns, further refining the wave impedance-porosity equivalent model for cavernous development zones.

[0166] Dynamic and static analysis suggests that 20 wells in Block H have encountered constant-volume cavernous reservoirs. By combining dynamic reserves, seismically etched volumes, and average wave impedance values, the relationship between porosity and P-wave impedance in the cavern sections can be established. Furthermore, the P-wave impedance volume can be converted into a porosity volume using linear or nonlinear cloud transformation. Taking Well-4 as an example, the calculated dynamic reservoir volume is 10,300 cubic meters, and the statically etched cavern volume is 120,000 cubic meters. The average porosity of this cavernous section is estimated at 8.5%, and the average wave impedance of the cavernous section encountered by this well is statistically estimated at 1.36 × 10⁷ kg / m³. 3 *m / s wave impedance. Referring to Table 1, the porosity of cavern reservoirs such as Well-12 and Well-5 was calculated using the same method. Figure 11 As shown, this refines the relationship between wave impedance and porosity in fractured-vuggy reservoirs with porosity greater than 8%, and updates the optimistic, expected, and pessimistic models of wave impedance and porosity. The fractured-vuggy sculpting method for fractured-vuggy carbonate reservoirs provided in this embodiment utilizes the dynamic reserves of a constant-volume cavernous reservoir for calibration, making the reserves of the secondary sculpted fractured-vuggy units more closely match the actual production conditions of the wells. Through the above examples, it is clear that compared to the static fractured-vuggy sculpting methods in the prior art, the method in this embodiment can more effectively correct uncertainties and improve the sculpting accuracy of fractured-vuggy reservoirs.

[0167] Table 1. Average porosity of caves calculated using a combination of dynamic and static methods.

[0168]

[0169] (3) Dynamic evaluation of reservoir connectivity

[0170] Reservoir connectivity assessment is a crucial aspect of reservoir dynamic analysis and description, as fracture distribution directly impacts reservoir connectivity. Field monitoring methods, such as tracer testing, inter-well microseismic analysis, and interference testing, are commonly used to directly assess inter-well connectivity. Additionally, production dynamic analysis methods, including injection-production response, pressure response, and production instability analysis, can also be used to identify inter-well connectivity. Furthermore, actual injection-production data can be fully utilized to rapidly and quantitatively assess inter-well connectivity. Existing models include multiple regression models, capacitance models, multi-well production indices, and flow network models. Among these, the capacitance model (CRM) is an injection rate time-delay model based on the principles of hydroelectric similarity and mass balance. It characterizes reservoir production data changes through connectivity coefficients, time-delay constants, and production indices, achieving a quantitative representation of connectivity. Therefore, applying the dynamic connectivity insights obtained from numerical well testing, production instability analysis, and CRM model analysis, a preferred equal-probability fracture-vuggy reservoir sculpting model is selected. This involves choosing the model consistent with the inter-well connectivity insights derived from dynamic analysis from among multiple equal-probability fracture-vuggy reservoir sculpting models established after considering the impact of uncertainties and the participation of dynamic information to reduce uncertainties.

[0171] Reference Figure 12a and Figure 12b As shown, dynamic analysis suggests that Well-1, Well-2, and Well-3 all encountered favorable fractures during drilling, but these fractures are not interconnected. (Refer to...) Figure 13a As shown, the double logarithmic curves from the well test exhibit characteristics of a constant-volume reservoir, referring to... Figure 13d As shown, the mass balance curve exhibits a single linear characteristic, which is characteristic of a constant-volume reservoir; refer to Figure 12a and Figure 12b As shown, Well-7 and Well-8 are located in the same interconnected slit, referencing... Figure 13b and Figure 13c As shown, the logarithmic curves from the well tests both exhibit characteristics of multiple cavern connections. Similarly, referring to... Figure 13e and Figure 13f As shown, the mass balance curve exhibits a linear characteristic in the early stage, followed by an upward curve in the later stage, representing the connectivity of the second fractured cavity. Furthermore, the dynamic reserves of constant-volume and interconnected reservoirs can be calculated using the mass balance curve.

[0172] Based on the above dynamic description process, the uncertainty of the fracture-vuggy reservoir sculpting model can be further reduced, and from multiple equally probable fracture-vuggy reservoir sculpting models, the preferred fracture-vuggy reservoir sculpting model whose reservoir connectivity conforms to dynamic understanding can be selected. (Refer to...) Figure 14a The model shown is implemented when the threshold values ​​for caves, dissolution cavities, and fractures are all low. The reservoir is distributed in contiguous areas with good connectivity, causing isolated wells to appear in the model as being within connected fractured cavities, which does not reflect reality. (Refer to...) Figure 14c The image shows a model sculpted when the threshold values ​​for caves, dissolution cavities, and fractures are all high. The reservoir is isolated and dispersed, leading to the disconnection of interconnected well groups as confirmed by dynamic analysis. (Refer to...) Figure 14b The diagram shows the results of a comprehensive carving of fractured-vuggy carbonate reservoirs based on the fractured-vuggy carving method provided in this invention. This method involves repeated adjustments to threshold values ​​using both dynamic and static methods. The final, optimized connectivity model is consistent with dynamic understanding. Comparison reveals that this result better reflects the actual connectivity of fractured-vuggy reservoirs. It should be noted that even within the same reservoir, considering uncertainties, reservoir connectivity can vary significantly. Therefore, the static carving model needs to be modified and optimized in conjunction with dynamic evaluation of reservoir connectivity.

[0173] (4) Optimization of the results of joint and cavity carving based on dynamic reserves

[0174] Uncertainties exist objectively in the process of carving fractured-vuggy carbonate reservoirs. By dynamically constraining and correcting the process through steps such as dynamic data-constrained geostatistical inversion, dynamic reserve correction of the wave impedance-porosity relationship of volumetric cavernous reservoirs, and dynamic connectivity optimization of fracture-vuggy models, the uncertainties of key nodes in the carving process are reduced, which in turn greatly reduces the uncertainty of the carving results.

[0175] To further reduce the uncertainties in fracture-vuggy reservoir carving, the inventors of this invention considered using dynamic reserve evaluation results to perform final optimization of fracture-vuggy reservoir models. The higher the match rate between the selected fracture-vuggy reservoir carving model and the evaluated dynamic reserves, the more reliable the model. For constant-volume cave-fractured reservoirs, isolated production is less affected by water bodies, and the calculated dynamic reserves are relatively reliable, which can be used as reliable well hard data to optimize static fracture-vuggy reservoir carving results. For fractured, fracture-vuggy, and fracture-pore reservoirs that are more affected by water bodies, the calculated dynamic reserve results are slightly less reliable and are used as reference well soft data to optimize fracture-vuggy reservoir carving results.

[0176] Based on at least one preferred fracture-vuggy reservoir sculpting model, fracture-vuggy sculpting calculations are performed to obtain at least one set of static geological reserves of fracture-vuggy reservoirs. The static geological reserves of fracture-vuggy reservoirs calculated by fracture-vuggy sculpting are compared with the dynamic reserves calculated by reservoir engineering methods. The fracture-vuggy reservoir sculpting model that is close to the dynamic reserves is selected as the final fracture-vuggy reservoir sculpting model. This final fracture-vuggy reservoir sculpting model is used as the basis model for subsequent geological models and numerical simulations, thereby further guiding oilfield development, production and practice.

[0177] Specifically, it can be referred to Figure 15a As shown, dynamic reserves were calculated for reliable and reference wells selected from Block H based on the production instability analysis method. The static geological reserves in the fractured-vuggy reservoir sculpting model of the reliable and reference wells were compared with the dynamic reserves calculated by the production instability analysis method. The model with the closest dynamic and static reserves was selected as the final fractured-vuggy reservoir sculpting model. (Refer to...) Figure 15b The image shows a static slotted storage collective engraving model obtained from the static slotted engraving method in the existing technology for block H, with reference to... Figure 15c The image shows the final fractured-vuggy reservoir sculpting model obtained from the fractured-vuggy carbonate reservoir sculpting method provided in this embodiment of the invention for block H. It is compared with... Figure 15b and Figure 15cIt can be observed that, due to the primary application of static fracture-vuggy reservoir carving using static seismic information and limited use of dynamic information, the carved reservoirs are mainly cavernous reservoirs with fewer pore reservoirs, relatively isolated distribution, and poor connectivity. The carved cavernous reservoir reserves are larger than the dynamically confirmed reserves, while the carved pore reservoir reserves are smaller. This indicates that static fracture-vuggy reservoir carving suffers from insufficient identification of effective reservoirs and inconsistencies with production dynamics. The fracture-vuggy reservoir carving method for fracture-vuggy carbonate reservoirs provided in this invention reduces uncertainty and improves the accuracy of the carving process and results by applying dynamic understanding to key nodes in fracture-vuggy reservoir carving (reservoir type ratio, quantitative analysis of isolated cavernous reservoirs, improvement of equivalent porosity models, connectivity evaluation, etc.). The final fracture-vuggy reservoir carving model shows that the reservoirs are mainly cavernous, fractured, and dissolution pores, with a significant increase in fractured-pore reservoirs. The well-controlled reservoir size is more consistent with the actual production-confirmed reserves. Inter-well connectivity evaluation confirms that Well-7 and Well-8 are connected well groups, while the rest are isolated wells. Figure 15b The static sculpted model of the cavernous storage complex failed to adequately describe the connectivity of block H, while Figure 15c The sculpting results of the final sculpted model of the cavern reservoir are clearly more consistent with the understanding of dynamic verification.

[0178] Example 2

[0179] Based on the same inventive concept, embodiments of the present invention also provide a fracture-cavity carving device for fracture-cavity carbonate reservoirs, referring to... Figure 16 As shown, it includes:

[0180] The first dynamic processing module 101 is used to determine the fractured-vuggy reservoir identification result based on the actual production dynamic data of the oil wells.

[0181] The wave impedance inversion module 102 is used to constrain the seismic wave impedance inversion based on the fractured-vuggy reservoir identification results and pre-acquired well data to obtain the wave impedance volume.

[0182] The first carving module 103 is used to carve the static contour volume and average wave impedance value of the constant volume cavern reservoir according to the wave impedance body.

[0183] The second dynamic processing module 104 is used to calculate the dynamic reserves of a fixed-volume cavern reservoir based on the fractured-vuggy reservoir identification results.

[0184] The second carving module 105 is used to calculate the average porosity value of the constant volume cavern reservoir based on the dynamic reserves, static profile volume and average wave impedance value of the constant volume cavern reservoir, and to establish a wave impedance-porosity equivalent model.

[0185] The third carving module 106 is used to establish multiple cave models and multiple dissolution cavity models based on multiple preset porosity threshold values ​​and the wave impedance-porosity equivalent model.

[0186] The fourth carving module 107 is used to predict earthquake cracks based on pre-acquired earthquake attribute information, determine earthquake crack phase models, and carve the earthquake crack phase models based on multiple preset earthquake parameter thresholds to establish multiple crack models.

[0187] The fifth carving module 108 is used to fuse the multiple crack models, the multiple cave models and the multiple dissolution cavity models to obtain multiple equally probable crack-cavity reservoir carving models.

[0188] The connectivity screening module 109 is used to screen the multiple equally probable fracture-vuggy reservoir collective carving models based on the pre-acquired inter-well connectivity relationship, and obtain at least one preferred fracture-vuggy reservoir collective carving model.

[0189] In this embodiment of the invention, the fracture-cavity carving device for fracture-cavity carbonate reservoirs described above is a device corresponding to the fracture-cavity carving method for fracture-cavity carbonate reservoirs provided in Embodiment 1 above. Its specific implementation can be referred to the detailed description of the fracture-cavity carving method for fracture-cavity carbonate reservoirs in Embodiment 1 above. In this embodiment of the invention, it will not be described again here.

[0190] Example 3

[0191] Based on the same inventive concept, this embodiment of the invention also provides a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the fracture-cavity carving method for fracture-cavity carbonate reservoirs as described in Embodiment 1.

[0192] Example 4

[0193] Based on the same inventive concept, embodiments of the present invention also provide a computer-readable storage medium storing a computer program that performs a fracture-cavity carving method for fracture-cavity carbonate reservoirs as described in Embodiment 1.

[0194] Other embodiments of this disclosure will readily occur to those skilled in the art upon consideration of the specification and practice of the disclosure herein. This application is intended to cover any variations, uses, or adaptations of this disclosure that follow the general principles of this disclosure and include common knowledge or customary techniques in the art not disclosed herein. The specification and examples are to be considered exemplary only, and the true scope and spirit of this disclosure are indicated by the following claims.

[0195] It should be understood that this disclosure is not limited to the precise structures described above and shown in the accompanying drawings, and various modifications and changes can be made without departing from its scope. The scope of this disclosure is limited only by the appended claims.

Claims

1. A method of fracture-vug sculpting of a fracture-vug carbonate reservoir, characterized by, include: Based on the actual production dynamic data of the oil wells, the fractured-vuggy reservoir type and the proportion of each fractured-vuggy reservoir are identified using a preset reservoir dynamic description method. The actual production dynamic data of the oil wells includes one or more of the following: drilling and logging information, acid fracturing modification information, well testing information, new well testing information, and production testing information. The fractured-vuggy reservoir type and the proportion of each fractured-vuggy reservoir are used as geostatistical information of probability density function, proportion relationship or variation function to constrain the process of seismic impedance inversion based on pre-acquired well data. The residual calculation of synthetic seismic record and model back control are performed by combining the seismic body to realize random simulation, and the impedance body is obtained. The static contour volume and average wave impedance value of the constant volume cavern reservoir are obtained by carving the wave impedance body. Based on the fracture-vuggy reservoir type and the proportion of each fracture-vuggy reservoir, the captive-type cavern reservoir group is determined; Based on the pre-defined reservoir engineering method, the dynamic reserves of a constant-volume cavern reservoir were calculated. The net volume of the constant-volume cavern reservoir is calculated based on the dynamic reserves of the constant-volume cavern reservoir and the pre-obtained fluid density. The average porosity value of the constant-volume cavern reservoir is calculated based on the net volume and static profile volume of the constant-volume cavern reservoir. Based on the average wave impedance and average porosity of the constant volume reservoir, an equivalent wave impedance-porosity model is established. Based on multiple preset porosity thresholds and the wave impedance-porosity equivalent model, multiple cave models and multiple dissolution cavities models are established. Based on the pre-acquired seismic attribute information, seismic crack prediction is performed, seismic crack phase model is determined, and the seismic crack phase model is sculpted based on multiple preset seismic parameter threshold values ​​to establish multiple crack models. By fusing the multiple crack models, the multiple cave models, and the multiple dissolution cavity models, multiple equally probable crack-cavity reservoir sculpted models are obtained. Based on the pre-obtained inter-well connectivity relationships, the multiple equally probable fracture-vuggy reservoir collective carving models are screened to obtain at least one preferred fracture-vuggy reservoir collective carving model.

2. The fracture-vug carbonate reservoir's fracture-vug sculpting method of claim 1, wherein, Also includes: Based on the obtained well-controlled dynamic reserves, the at least one preferred fractured-vuggy reservoir sculpting model is screened to obtain the final fractured-vuggy reservoir sculpting model.

3. The fracture-vuggy carbonate reservoir fracture-vuggy carving method as described in claim 2, characterized in that, The step of screening at least one preferred fractured-vuggy reservoir collective sculpting model based on the obtained well-controlled dynamic reserves to obtain the final fractured-vuggy reservoir collective sculpting model includes: Based on the at least one preferred fractured-vuggy reservoir carving model, fractured-vuggy carving calculations are performed to obtain the static geological reserves of at least one set of fractured-vuggy reservoirs. The well-controlled dynamic reserves are calculated based on the preset reservoir engineering method; The well-controlled dynamic reserves are matched with the static geological reserves of each group of fractured-vuggy reservoirs to obtain the matching results; The preferred fractured-vuggy reservoir sculpting model corresponding to the static geological reserves of the set of fractured-vuggy reservoirs with the highest matching rate in the matching results is determined as the final fractured-vuggy reservoir sculpting model.

4. The fracture vug carbonate reservoir's fracture vug carving method according to claim 1, characterized in that, The process of obtaining the static contour volume and average acoustic impedance value of a constant-volume cavern reservoir based on the acoustic impedance volume carving includes: Based on the statistical data of abnormal engineering conditions, the longitudinal wave impedance threshold value of the well venting location is obtained, and the upper limit value of the wave impedance of the constant volume cavern reservoir is determined. Based on the upper limit of the wave impedance, the wave impedance body is sculpted using a preset three-dimensional sculpting method to depict the spatial shape, static contour volume and average wave impedance value of the wave impedance body.

5. A fracture-cave carving device for a fracture-cave carbonate reservoir, characterized by, include: The first dynamic processing module is used to identify and determine the fractured-vuggy reservoir type and the proportion of each fractured-vuggy reservoir based on the actual production dynamic data of the oil wells obtained and a preset reservoir dynamic description method. The actual production dynamic data of the oil wells includes one or more of the following: drilling and logging information, acid fracturing modification information, oil testing information, new well testing information, and production testing information. The seismic impedance inversion module is used to constrain the process of seismic impedance inversion based on pre-acquired well data by using the fractured-vuggy reservoir type and the proportion of each fractured-vuggy reservoir as geostatistical information such as probability density function, proportion relationship or variation function, and to combine the seismic body to realize the stochastic simulation to calculate the residual of the synthetic seismic record and the model back control to obtain the seismic impedance body. The first carving module is used to carve the static contour volume and average wave impedance value of the constant volume cavern reservoir according to the wave impedance body. The second dynamic processing module is used to determine the capacitive cavern reservoir based on the fracture-cavity reservoir type and the proportion of each fracture-cavity reservoir; and to calculate the dynamic reserves of the capacitive cavern reservoir based on a preset reservoir engineering method. The second carving module is used to calculate the net volume of the constant-volume cavern reservoir based on the dynamic reserves and pre-acquired fluid density; calculate the average porosity value of the constant-volume reservoir based on the net volume and static profile volume of the constant-volume cavern reservoir; and establish a wave impedance-porosity equivalent model based on the average wave impedance value and average porosity value of the constant-volume reservoir. The third carving module is used to establish multiple cave models and multiple dissolution cavity models based on multiple preset porosity threshold values ​​and the wave impedance-porosity equivalent model. The fourth carving module is used to predict earthquake cracks based on pre-acquired earthquake attribute information, determine earthquake crack phase models, and carve the earthquake crack phase models based on multiple preset earthquake parameter thresholds to establish multiple crack models. The fifth carving module is used to fuse the multiple crack models, the multiple cave models, and the multiple dissolution cavity models to obtain multiple equally probable crack-cavity reservoir carving models. The connectivity screening module is used to screen the multiple equally probable fracture-vuggy reservoir collective carving models based on the pre-acquired inter-well connectivity relationships, and obtain at least one preferred fracture-vuggy reservoir collective carving model.

6. A computer device comprising a memory, a processor, and a computer program stored on the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the fracture-cavity carving method for fracture-cavity carbonate reservoirs as described in any one of claims 1-4.

7. A computer readable storage medium characterized by, The computer-readable storage medium stores a computer program that performs the fracture-cavity carving method for fracture-cavity carbonate reservoirs as described in any one of claims 1-4.

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