CN110308487B - Quantitative characterization method for solution-fractured oil reservoir - Google Patents
Quantitative characterization method for solution-fractured oil reservoir Download PDFInfo
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Abstract
The invention provides a quantitative characterization method of a dissolved-fractured reservoir, which comprises the following steps: establishing a development mode of the ampullate; taking the development mode of the amputative solvent as a guide to predict the earthquake of the characteristics of the amputative solvent; establishing a three-dimensional geological model of the solution reservoir by taking a karst development mode as guidance; and correcting the three-dimensional geological model of the solution reservoir based on the production dynamic data. The method for quantitatively characterizing the solution-breaking oil reservoir fully considers the development mode of the solution-breaking oil reservoir, establishes the distribution of the external profile, the internal characteristic and the attribute parameter of the solution-breaking oil reservoir respectively by adopting a well-seismic combined geological modeling method on the basis of the correlation attributes of the solution-breaking oil predicted by the geophysical method, quantitatively characterizes the characteristics of the solution-breaking oil reservoir, and can provide reliable basis for reserve evaluation, numerical simulation and development scheme adjustment.
Description
Technical Field
The invention relates to the technical field of oil and gas field development, in particular to a quantitative characterization method of an oil reservoir with an interrupted solution type.
Background
The fracture-solution type oil reservoir mainly refers to a fracture-cavity system which is formed by erosion of fracture zones in and around a fracture zone to form different spatial structures due to the fact that a brittle limestone fracture zone developed along fracture is formed under the action of a structure and karst water seeps downwards or upwells along the fracture direction. The karst fractured-vuggy carbonate reservoir belongs to a fractured-vuggy carbonate reservoir, is a karst fractured-vuggy body development favorable zone controlled by deep and large fractures, and has obvious characteristic of controlling the karst. The development of the fractured-solution reservoir in the mining field is initially successful, and drilling an oil well with more than one hundred tons of output faces the problem of further designing and optimizing a development scheme, and fine reservoir description and three-dimensional geological modeling need to be carried out on the fractured-solution reservoir, so that the research on the quantitative characterization method of the fractured-solution reservoir is of great significance.
Currently, the relevant research on the solution-type reservoir mainly includes: luxin feces et al (the character and development practice of carbonate dissolved-fluid reservoir in Tahe area, Luxin feces et al, oil and gas geology, vol. 36, No. 3, p. 347-Bu 355, in 2015, 6 months) propose the character and development condition of carbonate dissolved-fluid reservoir in Tahe area, consider that after multi-phase structural deformation and karst action, the carbonate rock stratum in the Alotus coverage area in Tahe area forms various irregular crack-cavities along large-scale corrosion fracture zone, and utilize the fine coherence, amplitude change rate, earthquake time slicing and other technologies of high-precision three-dimensional earthquake, combine with field outcrop, mass drilling data and production dynamic data to make comprehensive research, propose the theoretical concept of solution trapping, explain the formation mechanism and characteristics of the broken-fluid reservoir in the Alotus coverage area in Tahe, divide it into strip-shaped zones according to its space distribution form and control factors, The strip-shaped solution-breaking oil reservoir has the advantages that the strip-shaped solution-breaking oil reservoir has the best development effect. The patent application CN107083939A discloses a three-dimensional development method for a carbonate rock solution reservoir, which comprises the steps of determining the external profile of a carbonate rock solution reservoir by utilizing seismic data, determining the spatial position of a distributed fracture hole in the carbonate rock solution reservoir according to seismic attributes, determining the connectivity of the fracture hole according to the spatial position of the fracture hole, and deploying an oil well based on the fracture hole distribution and the connectivity of the fracture hole distribution so as to carry out three-dimensional development on the carbonate rock solution reservoir. Patent application CN107191175A discloses an injection-production well pattern construction method for carbonate rock solution reservoir, which comprises the following steps: identifying and characterizing a fracture-cave structure of the carbonate rock solution reservoir by a geophysical method, establishing a mechanism model of the carbonate rock solution reservoir based on the characterization and concept model of the fracture-cave structure, and designing an injection-production well pattern of the carbonate rock solution reservoir according to the mechanism model.
The research describes and describes the solution reservoir through multidisciplinary data, seismic means are adopted for predicting the solution reservoir, the characterization of the reservoir is qualitative description, the guidance of a karst development mode is removed, the scale volume, physical property parameters and reserve size of the reservoir cannot be quantitatively evaluated, the solution reservoir is not quantitatively characterized, and accurate geological basis is difficult to provide for the design and optimization of a reservoir development scheme.
Disclosure of Invention
In order to solve the technical problem, the invention provides a quantitative characterization method of an oil reservoir of an interrupted solution type under the restriction of a karst development mode.
A method for quantitatively characterizing a solution-fractured reservoir is characterized by comprising the following steps of:
s101, establishing an episome development mode;
s102, conducting earthquake prediction of the characteristics of the episome by taking the development mode of the episome as guidance;
s103, establishing a three-dimensional geological model of the solution reservoir by taking a karst development mode as a guide and combining with a seismic prediction result; the method specifically comprises the following steps:
establishing a correlation between seismic structure tensor attributes and well point drilling fractured fluid by taking a fractured fluid development mode as guidance, establishing a fractured fluid outline initial model by adopting a target-based method, and manually correcting the initial model by combining boundary information reflected by dynamic characteristics and the fractured fluid development mode to establish a fractured fluid external outline model;
on the basis of an external contour model, a space distribution model of solution cavities, corrosion cavities and multi-scale cracks in the solution is established in a classified mode, and the internal communication and segmentation characteristics of the solution are further determined by combining with the dynamic production characteristics;
respectively establishing different groups of fracture models according to the fracture information and the fracture parameters;
on the basis of respectively establishing external forms and internal feature models of the fractured fluid, respectively adopting a karst phase control and equivalent method to establish attribute models of different types of reservoirs;
and fusing the external contour model and the internal reservoir body distribution characteristics to obtain a dissolved body breaking model, and fusing different types of reservoir body attribute models to obtain a dissolved body breaking overall attribute model.
And S104, correcting the three-dimensional geological model of the solution reservoir based on the production dynamic data to obtain an accurate geological model.
Further, the correcting the three-dimensional geological model of the solution reservoir based on the production dynamic data comprises:
correcting the development depth of the reservoir through the flow temperature change and the ground temperature gradient in the production process;
correcting the reservoir type around the perforation segment of the production well through the dynamically judged reservoir type;
correcting porosity, permeability and saturation parameters of the model through production history data;
correcting the geological reserves communicated with the perforation section of the production well through the dynamically judged reserves for the control of the production well;
optimizing the communication condition of the reservoir in the model according to the communication judgment result of the wells;
and correcting the average physical property parameters of the model around the well through the reservoir parameters of well testing and production dynamic analysis inversion.
Further, the seismic prediction includes predicting external shape, internal characteristics, and attribute parameters of the solution reservoir.
Further, the seismic prediction comprises:
determining an interrupted layer of an oil reservoir by using manual interpretation, determining large-scale fracture by using seismic coherence, predicting a micro-fracture and fracture distribution rule by using curvature attributes, and predicting an interrupted solution boundary and an external form by using seismic gradient structure tensor attributes in combination with production dynamic characteristics;
predicting a large-scale karst cave reservoir body in the fractured karst by utilizing a seismic wave impedance inversion body and a frequency division energy body;
and (3) depicting a small-scale erosion hole reservoir body by utilizing the gradient attribute of the seismic amplitude spectrum, and determining small-scale fracture and micro fracture by utilizing the fracture enhancement attribute and combining the attribute of the seismic ant body.
Preferably, the calculation procedure of the seismic gradient structure tensor attribute includes:
removing bad tracks, collecting footprints and filtering noise in the original earthquake;
constructing a tensor gradient vector body, an edge detection body and a voxel density enhancing body;
and calculating the seismic gradient structure tensor attribute body.
Preferably, the method for predicting the large-scale karst cave reservoir by using the seismic frequency division energy body comprises the following steps: seismic data volume spectrum analysis;
extracting a target curve for learning frequency division attributes;
and calculating a target data volume.
Preferably, the method for depicting the small-scale erosion hole reservoir body by utilizing the seismic amplitude spectrum gradient attribute comprises the steps of establishing a change relation between seismic amplitude and frequency in an effective frequency band of seismic data, and predicting the small-scale erosion hole reservoir body according to the relation.
Preferably, the combined production dynamic characteristics further determine the internal communication and segmentation characteristics of the solution, and include:
judging an inter-well communication channel by adopting a tracer test or a production dynamic response method or a similar interference method;
determining a communication mode between reservoirs through a communication channel between wells by combining the distribution characteristics and the opening conditions of cracks and karst caves with different scales;
and determining a segmentation pattern by means of segmentation judgment of fracture, reservoir filling judgment and combination of the communication characteristics.
Preferably, the method for fusing the attribute models of the different types of reservoirs specifically comprises the following steps: assigning values to the same position condition; the method for fusing the external contour model and the internal reservoir distribution characteristics specifically comprises the following steps: a method in which a reservoir predominates, non-reservoir assignment is a matrix.
Compared with the prior art, the method for quantitatively characterizing the solution-breaking oil reservoir mainly utilizes seismic attributes to qualitatively depict the solution-breaking oil reservoir and is difficult to quantify, fully considers the development mode of the solution-breaking oil reservoir, adopts a well-seismic combined geological modeling method based on different seismic attributes related to solution-breaking predicted by geophysics, respectively establishes distribution models of external profiles, internal characteristics and attribute parameters of the solution-breaking oil reservoir, corrects the models through production dynamic information, quantitatively characterizes the heterogeneity characteristics of the solution-breaking oil reservoir, and can provide reliable basis for reserve evaluation, numerical simulation and development scheme adjustment.
The features mentioned above can be combined in various suitable ways or replaced by equivalent features as long as the object of the invention is achieved.
Drawings
The invention will be described in more detail hereinafter on the basis of non-limiting examples only and with reference to the accompanying drawings. Wherein:
FIG. 1 is a flow chart of a method for quantitative characterization of a solution-fractured reservoir of the present invention;
FIG. 2 is a graph of the S-block lysosome-disrupting development pattern according to an embodiment of the present invention;
FIG. 3 is a graph of S-block seismic structure tensor property prediction for an effect of an interrupted solvent contour according to the embodiment shown in FIG. 2;
FIG. 4 is a flow chart of the S-block building of a three-dimensional geological model of an fractured fluid according to the embodiment shown in FIG. 2;
FIG. 5 is a result of S-block solution break profile modeling according to the embodiment shown in FIG. 2;
FIG. 6 is a S-block solution internal cavern reservoir distribution model according to the embodiment shown in FIG. 2;
FIG. 7 is a S-block internal erosion vug reservoir distribution model according to the embodiment shown in FIG. 2;
FIG. 8 is a S-block solution-fractured discrete large-scale fracture model according to the embodiment shown in FIG. 2;
FIG. 9 is a discrete mesoscale fracture model of an S-block solution reservoir according to the embodiment shown in FIG. 2;
FIG. 10 is a probability volume for small inter-well fracture density fusion of the S-patch according to the embodiment shown in FIG. 2;
FIG. 11 is a set of NE25 ° small scale fracture models in an S-block solution reservoir according to the embodiment shown in FIG. 2;
FIG. 12 is a three-dimensional geological model of an S-block solution reservoir according to the embodiment shown in FIG. 2;
FIG. 13 is a S-block solution reservoir property model according to the embodiment shown in FIG. 2;
Detailed Description
The invention will be described in further detail below with reference to the drawings and specific examples. It should be noted that, as long as there is no conflict, the embodiments and the features of the embodiments of the present invention may be combined with each other, and the technical solutions formed are within the scope of the present invention.
As shown in figure 1, the quantitative characterization method of the solution-fractured reservoir comprises the following steps:
s101, establishing an episome development mode;
s102, conducting earthquake prediction of the characteristics of the episome by taking the development mode of the episome as guidance;
s103, establishing a three-dimensional geological model of the solution reservoir by taking a karst development mode as a guide and combining with a seismic prediction result; the method specifically comprises the following steps:
establishing a correlation between seismic structure tensor attributes and well point drilling fractured fluid by taking a fractured fluid development mode as guidance, establishing a fractured fluid outline initial model by adopting a target-based method, and manually correcting the initial model by combining boundary information reflected by dynamic characteristics and the fractured fluid development mode to establish a fractured fluid external outline model;
on the basis of an external contour model, a space distribution model of solution cavities, corrosion cavities and multi-scale cracks in the solution is established in a classified mode, and the internal communication and segmentation characteristics of the solution are further determined by combining with the dynamic production characteristics;
respectively establishing different groups of fracture models according to the fracture information and the fracture parameters;
on the basis of respectively establishing external forms and internal feature models of the fractured fluid, respectively adopting a karst phase control and equivalent method to establish attribute models of different types of reservoirs;
and fusing the external contour model and the internal reservoir body distribution characteristics to obtain a dissolved body breaking model, and fusing different types of reservoir body attribute models to obtain a dissolved body breaking overall attribute model.
And S104, correcting the three-dimensional geological model of the solution reservoir based on the production dynamic data to obtain an accurate geological model.
Further, the production dynamics-based data correction model includes:
correcting the development depth of the reservoir through the flow temperature change and the ground temperature gradient in the production process;
correcting the reservoir type around the perforation segment of the production well through the dynamically judged reservoir type;
correcting porosity, permeability and saturation parameters of the model through production history data;
correcting the geological reserves communicated with the perforation section of the production well through the dynamically judged reserves for well control;
optimizing the communication condition of the reservoir in the model according to the communication judgment result of the wells;
and correcting the average physical property parameters of the model around the well through the reservoir parameters of well testing and production dynamic analysis inversion.
Further, seismic prediction includes predicting external shape, internal characteristics, and attribute parameters of the solution reservoir.
Further, the seismic prediction includes:
determining an interruption layer of an oil reservoir by using manual interpretation, determining large-scale fracture by using seismic coherence, predicting a micro-fracture and fracture distribution rule by using curvature attributes, and predicting an interruption solution boundary and an external form by using seismic gradient structure tensor attributes in combination with production dynamic characteristics;
predicting a large-scale karst cave reservoir body in the fractured karst by utilizing a seismic wave impedance inversion body and a frequency division energy body;
and (3) depicting a small-scale erosion hole reservoir body by utilizing the gradient attribute of the seismic amplitude spectrum, and determining small-scale fracture and micro fracture by utilizing the fracture enhancement attribute and combining the attribute of the seismic ant body.
Preferably, the basic principle of the seismic gradient structure tensor is to construct seismic data into three-dimensional image data attributes, determine the structural attributes of different texture units (such as waves, layers, disordered reflections and the like) in the seismic image data based on the relative size of characteristic values and combination parameters of local structure tensor, and automatically identify reflection abnormal bodies.
The calculation flow of the seismic gradient structure tensor attribute comprises the following steps:
removing bad tracks, collecting footprints and filtering noise in the original earthquake;
constructing a tensor gradient vector body, an edge detection body and a voxel density enhancing body;
calculating the display of a seismic gradient structure tensor attribute body, highlighting the disordered reflection of a fracture zone through a calculation process, calculating to obtain tensor gradient, realizing voxel enhancement and predicting the profile of the fracture solution.
Preferably, the seismic frequency-division energy volume prediction large-scale karst cave reservoir flow comprises the following steps:
seismic data volume spectrum analysis, including analyzing seismic data quality, determining extraction frequency range and the like;
frequency division attribute extraction target curve learning, frequency division processing is carried out on original seismic data, different frequency amplitude attributes are extracted, target curve training is participated, and a mapping relation from logging information to seismic information is obtained;
and calculating a target data volume, and calculating an inversion target data volume according to the mapping relation of the amplitude and the frequency.
The method for predicting the large-scale karst cave reservoir body by utilizing the seismic frequency-division energy body has the basic principle that the relation between time thickness and amplitude under different frequencies and the relation between frequency and amplitude under different time thicknesses are analyzed, an acoustic curve reflecting lithology and physical property change trends is taken as a training target curve, and the mapping relation from seismic waveform information to the target curve is obtained. The mapping relation fuses the change information between the amplitude and the frequency, and accordingly the target attribute inversion body can be obtained.
Preferably, the method for depicting the small-scale erosion hole reservoir body by utilizing the seismic amplitude spectrum gradient attribute comprises the steps of establishing a change relation between seismic amplitude and frequency in an effective frequency band of seismic data, and predicting the small-scale erosion hole reservoir body according to the relation. The method highlights the permeability of the reservoir, amplifies the seismic response characteristics of the small-scale reservoir, establishes a calculation formula between the seismic reflection coefficient and the rock skeleton, the rock permeability, the fluid contained in the rock and the seismic frequency, and achieves the purpose of predicting the small-scale erosion hole reservoir. The amplitude spectrum gradient attribute can reflect the reservoir boundary and the internal characteristics, and is more favorable for the space depiction of the small-scale erosion hole reservoir.
Further, the method for establishing the three-dimensional geological model of the solution reservoir by taking the karst development mode as a guide and combining with the earthquake prediction result comprises the following steps:
establishing a correlation between seismic structure tensor attributes and well point drilling fractured fluid by taking a fractured fluid development mode as guidance, establishing a fractured fluid outline initial model by adopting a target-based method, and manually correcting the initial model by combining boundary information reflected by dynamic characteristics and the fractured fluid development mode to establish a fractured fluid external outline model;
on the basis of an external contour model, a space distribution model of solution cavities, corrosion cavities and multi-scale cracks in the solution is established in a classified mode, and the internal communication and segmentation characteristics of the solution are further determined by combining with the dynamic production characteristics;
respectively establishing different groups of fracture models according to the fracture information and the fracture parameters;
on the basis of respectively establishing external forms and internal feature models of the fractured fluid, respectively adopting a karst phase control and equivalent method to establish attribute models of different types of reservoirs; performing porosity and permeability modeling on the karst cave and the erosion cave by respectively adopting a sequential Gaussian simulation method of karst phase control; and (3) modeling porosity and permeability of the crack by adopting an equivalent method, determining the equivalent permeability of the single crack by adopting a parallel plate model and a cubic law based on crack opening information, and coarsening the crack attribute to a corresponding grid system by utilizing an Oda method to obtain the equivalent physical property parameter of the crack. The karst phase control method is to utilize a karst cave distribution model to restrain the simulation of the physical properties of the whole karst cave and utilize an erosion hole distribution model to restrain the simulation of the physical properties of the erosion holes.
And fusing the external contour model and the internal reservoir body distribution characteristics to obtain a dissolved body breaking model, and fusing different types of reservoir body attribute models to obtain a dissolved body breaking overall attribute model. Preferably, the method for fusing the attribute models of the different types of reservoirs is a homotopic condition value-assigning method; the method of fusing the external contour model with the internal reservoir distribution characteristics is a method of reservoir dominance and non-reservoir assignment as a matrix.
Preferably, the combined production dynamic characteristics further determine the internal communication and segmentation characteristics of the solution, and include:
firstly, judging an inter-well communication channel by adopting a tracer test or a production dynamic response method or a similar interference method; preferably, the inter-well communication judging method comprises a tracer test for a well with tracer information, a production dynamic response method for an injection and production well group without tracer information and a production well group interference method without tracer information. The similar interference method carries out comprehensive judgment by methods of consistent water breakthrough time, reduced pressure trend, correlation of production characteristics, newly-built production well interference, well shut-in interference and the like.
Secondly, determining a communication mode between reservoirs through a communication channel between wells by combining the distribution characteristics and opening conditions of cracks and karst caves with different scales; wherein the pattern of communication between the reservoirs comprises: crack communication, crack-hole communication, crack-karst cave communication, river communication, etc.
And finally, determining a segmentation pattern by means of segmentation judgment of fracture, reservoir filling judgment and combination of the communication characteristics.
The quantitative characterization method of the solution-fractured reservoir fully considers the development mode of the solution-fractured reservoir of the fracture-vug reservoir, and respectively establishes models of the external profile, the internal characteristics and the attribute parameters of the solution-fractured reservoir by taking the karst development mode and the geophysical prediction result as the basis and combining well and earthquake with a method combining deterministic modeling and random simulation, so that dynamic and static data are combined to effectively fuse multiple models, thereby realizing the quantitative characterization of the spatial distribution and the physical characteristics of the reservoir, and carrying out reserve evaluation and numerical simulation by taking the models as the basis, thereby laying a reliable basis for deploying and optimizing the development scheme.
According to the quantitative characterization method for the solution-fractured reservoir provided by the invention, an S block is taken as an example and is implemented on site.
The region where the S block is located in an ancient humped structural zone and is controlled by north-east deep fracture on a slope, the fracture is mainly divided into sliding and pulling, extrusion is mainly performed in the north-west direction, the activity period is mainly the Jia Li Dong period and the Hai xi period, the main fracture structural style of the region is flat-plate-shaped fracture and flower-shaped fracture, the transverse difference of different fracture zones is obvious, different sections in a unified fracture zone are different in development characteristics, the pulling section develops negative flower-shaped solution, the extrusion section develops positive flower-shaped solution, and the translation section develops flat-plate-shaped solution.
S101, according to core observation and knowledge of the S-block oil reservoir, the development condition of the fault-control reservoir is investigated by combining field outcrop, and an S-block fault-solution development mode shown in figure 2 is established.
By judging that the S block is positioned at the broken tensile section, the types of karst caves, corrosion caves, cracks of different levels and the like are developed around the broken section, the distribution range of the upper reservoir body is larger, the reservoir body gradually becomes a reduction trend along the broken section and is in a negative flower shape integrally, and accordingly, the S block broken karst development mode is established.
And S102, respectively predicting the external shape and the internal characteristics of the solution reservoir by using different seismic attributes and taking the solution development mode as guidance.
The earthquake section of the inner edge of the S zone takes chaotic reflection as the main part, and strong beaded reflection energy is weaker, which indicates that the large-scale karst cave reservoir body is less developed and the small-scale karst cave reservoir body is more developed along the fracture.
The prediction step comprises:
firstly, determining an interruption layer of an oil reservoir by using manual interpretation, determining large-scale fracture by using seismic coherence, predicting micro-fracture and fracture distribution rules by using curvature attributes, and predicting an interruption solution boundary and external form by using seismic gradient structure tensor attributes in combination with production dynamic characteristics. The predicted solution profile results are shown in fig. 3.
Secondly, predicting a large-scale karst cave reservoir body in the broken karst by using a seismic wave impedance inversion body and a frequency division energy body, and depicting a small-scale karst cave reservoir body by using the gradient attribute of a seismic amplitude spectrum; and determining small-scale fracture and micro fracture by utilizing fracture enhancement property and combining with the property of the earthquake ant body.
And S103, establishing a three-dimensional geological model of the fractured fluid by taking a karst development mode as a guide, utilizing geophysical prediction and dynamic analysis results and adopting a method combining deterministic modeling and random simulation. The specific steps are shown in fig. 4:
And 2, on the basis of the external contour model, establishing space distribution models of solution cavities, corrosion cavities and multi-scale cracks in the solution, and further determining the internal communication and segmentation characteristics of the solution by combining with the dynamic characteristics of production. The method comprises the steps of integrating wave impedance inversion and frequency division energy attributes, preferably reflecting large-scale karst cave reservoir regions as large karst cave modeling constraints among wells, and establishing a karst cave reservoir distribution model inside the broken karst cave as shown in figure 6 by adopting a target-based method; the erosion hole model shown in fig. 7 is established by using the amplitude spectrum gradient attribute as the constraint condition of the interwell seismic attribute, using the karst cave reservoir model as the constraint condition of the karst cave development cause and adopting a method of sequential indication random simulation.
Step 3, taking fractures extracted by manually explaining faults and ant tracking as deterministic information, and establishing a discrete large-scale fracture model shown in the figure 8 and a discrete medium-scale fracture model shown in the figure 9 by adopting a deterministic method;
respectively establishing 3 probability bodies of a target position to a karst cave, a distance to a fault and an earthquake fracture enhancement prediction result on the basis of fracture density established by a single well, and fusing the 3 probability bodies into 1 probability body for restraining the development density of the fractures among wells by calibrating with well points, wherein the fusion result is shown in figure 10;
and respectively establishing different groups of fracture models by a random modeling method under the conditions of the established inter-well fracture density as a constraint and the parameters of fracture opening, attitude and the like determined by well points, wherein as shown in figure 11, the different groups of fracture models are a group of NE25 small-scale discrete fracture models in an S-block solution reservoir.
And 4, respectively adopting a karst phase control and equivalent method to establish attribute models of different types of reservoirs on the basis of respectively establishing external forms and internal feature models of the fractured fluid. The karst phase control method is characterized in that a karst cave distribution model is used for restraining the physical simulation of the whole karst cave, and an erosion cave distribution model is used for restraining the physical simulation of the erosion caves.
Performing porosity and permeability modeling on the karst cave and the erosion cave by respectively adopting a sequential Gaussian simulation method of karst phase control; and (3) modeling porosity and permeability of the crack by adopting an equivalent method, determining the equivalent permeability of the single crack by adopting a parallel plate model and a cubic law based on crack opening information, and coarsening the crack attribute to a corresponding grid system by utilizing an Oda method to obtain the equivalent physical property parameter of the crack.
And 5, fusing the external contour model and the internal reservoir body distribution characteristics to obtain an interrupted solution body model, and fusing different types of reservoir body attribute models to obtain an interrupted solution body overall attribute model. The three-dimensional geological model modeling result of the S-block solution reservoir is shown in FIG. 12.
Preferably, the fusing method of the internal reservoirs of the episome is an orthotopic condition assigning method; the internal reservoir and external contour model fusion method is a reservoir-dominated, non-reservoir-valued matrix method.
And S104, obtaining an accurate geological model after correction based on the production dynamic data. And then acquiring reservoir body and physical property quantitative parameters and distribution proportion of the solution reservoir based on the three-dimensional geological model, and quantitatively representing the profile, the reservoir body distribution and the attribute characteristics of the solution reservoir. The results of the attribute parameter modeling of the S-block solution reservoir are shown in FIG. 13.
According to the graph shown in fig. 2, the proportion of the volume of the solution breaking body is determined to be 39.1% based on the three-dimensional geological model, wherein the proportion of the solution cavity is 6.5%, the proportion of the corrosion cavity is 33.1%, and the proportion of the non-reservoir body is 60.4%; the porosity range of the karst cave is 2.2-15.6%, and the permeability range is 50-500 md; the porosity range of the erosion holes is 2% -7.2%, and the permeability range is 30-170 md; the integral storage capacity of the solution is 460 ten thousand tons, wherein the storage capacity of the solution cavity is 183.2 ten thousand tons, the storage capacity of the corrosion cavity is 220.5 ten thousand tons, and the storage capacity of other reservoirs is 56.3 ten thousand tons.
The accuracy and superiority of the method are verified through the S region embodiment, and compared with the conventional geophysical prediction method, the method can obtain a quantitative model for representing the dissolved-fluid reservoir. The method for quantitatively characterizing the solution-breaking oil reservoir fully considers the development mode of the solution-breaking oil reservoir, establishes the distribution of the external contour, the internal characteristic and the attribute parameter of the solution-breaking body respectively by adopting a well-seismic combined geological modeling method on the basis of the correlation attribute of the solution-breaking body predicted by the geophysical method, quantitatively characterizes the characteristics of the solution-breaking oil reservoir, and can provide reliable basis for reserve evaluation, numerical simulation and development scheme adjustment.
Thus, it will be appreciated by those skilled in the art that while a number of illustrative embodiments of the invention have been shown and described in detail herein, many other variations or modifications can be made, directly or by derivation of teachings consistent with the principles of the invention without departing from the spirit or scope thereof, and thus, the scope of the invention should be understood and considered to cover all such other variations or modifications.
Moreover, while the operations of the invention are depicted in the drawings in a particular order, this does not necessarily imply that the operations must be performed in that particular order, or that all of the operations shown must be performed, to achieve desirable results. Certain steps may be omitted, multiple steps combined into one step or a step divided into multiple steps performed.
While the invention has been described with reference to a preferred embodiment, various modifications may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In particular, the technical features mentioned in the embodiments can be combined in any way as long as no conflict exists. It is intended that the invention not be limited to the particular embodiments disclosed, but that the invention will include all embodiments falling within the scope of the appended claims.
Claims (9)
1. A method for quantitatively characterizing a solution-fractured reservoir is characterized by comprising the following steps of:
establishing a development mode of the ampullate;
taking the development mode of the amputative solvent as a guide to predict the earthquake of the characteristics of the amputative solvent;
establishing a three-dimensional geological model of the solution reservoir by taking a karst development mode as guidance and combining with a seismic prediction result;
correcting the three-dimensional geological model of the solution reservoir based on the production dynamic data;
the method comprises the following steps of establishing a three-dimensional geological model of an oil reservoir with a karst development mode as a guide in combination with an earthquake prediction result, wherein the three-dimensional geological model comprises the following steps:
establishing a correlation between seismic structure tensor attributes and well point drilling fractured fluid by taking a fractured fluid development mode as guidance, establishing a fractured fluid outline initial model by adopting a target-based method, and manually correcting the initial model by combining boundary information reflected by dynamic characteristics and the fractured fluid development mode to establish a fractured fluid external outline model;
on the basis of an external contour model, a space distribution model of solution cavities, corrosion cavities and multi-scale cracks in the solution is established in a classified mode, and the internal communication and segmentation characteristics of the solution are further determined by combining with the dynamic production characteristics;
respectively establishing different groups of fracture models according to the fracture information and the fracture parameters;
on the basis of respectively establishing external forms and internal feature models of the fractured fluid, respectively adopting a karst phase control and equivalent method to establish attribute models of different types of reservoirs;
and fusing the external contour model and the internal reservoir body distribution characteristics to obtain an interrupted solution body attribute model, and fusing different types of reservoir body attribute models to obtain an interrupted solution body integral attribute model.
2. The method of claim 1, wherein correcting the three-dimensional geological model of the fractured-fluid reservoir based on the production dynamics data comprises:
correcting the development depth of the reservoir through the flow temperature change and the ground temperature gradient in the production process;
correcting the reservoir type around the perforation segment of the production well through the dynamically judged reservoir type;
correcting porosity, permeability and saturation parameters of the model through production history data;
correcting the geological reserves communicated with the perforation section of the production well through the well control reserve calculated dynamically;
optimizing the communication condition of the reservoir in the model according to the communication judgment result of the wells;
and correcting the average physical property parameters of the model around the well through the reservoir parameters of well testing and production dynamic analysis inversion.
3. The method of quantitative characterization of an oil-fractured-fluid reservoir of claim 1, wherein the seismic prediction comprises predicting external shape, internal characteristics and attribute parameters of the oil-fractured-fluid reservoir.
4. The method of claim 3, wherein the seismic prediction comprises:
determining an interrupted layer of an oil reservoir by using manual interpretation, determining large-scale fracture by using seismic coherence, predicting a micro-fracture and fracture distribution rule by using curvature attributes, and predicting an interrupted solution boundary and an external form by using seismic gradient structure tensor attributes in combination with production dynamic characteristics;
predicting a large-scale karst cave reservoir body in the fractured karst by utilizing a seismic wave impedance inversion body and a frequency division energy body;
and (3) depicting a small-scale erosion hole reservoir body by utilizing the gradient attribute of the seismic amplitude spectrum, and determining small-scale fracture and micro fracture by utilizing the seismic fracture enhancement attribute and combining the attribute of the seismic ant body.
5. The method for quantitatively characterizing an immiscible-solution reservoir according to claim 4, wherein the method for calculating the tensor properties of the seismic gradient structure comprises:
removing bad tracks, collecting footprints and filtering noise in the original earthquake;
constructing a tensor gradient vector body, an edge detection body and a voxel density enhancing body;
and calculating the seismic gradient structure tensor attribute body.
6. The method for quantitatively characterizing the fractured-fluid reservoir according to claim 4, wherein the method for predicting the large-scale karst cave reservoir by using the seismic fractional energy body comprises the following steps:
seismic data volume spectrum analysis;
extracting a target curve for learning frequency division attributes;
and calculating a target data volume.
7. The method for quantitatively characterizing an absolutely soluble fluid reservoir according to claim 4, wherein the method for characterizing a small-scale erosion vug reservoir by using the seismic amplitude spectrum gradient attribute comprises: and in the effective frequency band of the seismic data, establishing a variation relation between the seismic amplitude and the frequency, and predicting the small-scale erosion hole reservoir body according to the relation.
8. The method for quantitatively characterizing an oil reservoir of the type with broken solution according to claim 1, wherein the further determining the internal communication and segmentation characteristics of the broken solution by combining with the production dynamic characteristics comprises:
judging an inter-well communication channel by adopting a tracer test or a production dynamic response method or a similar interference method;
determining a communication mode between reservoirs through a communication channel between wells by combining the distribution characteristics and the opening conditions of cracks and karst caves with different scales;
and determining a segmentation pattern by means of segmentation judgment of fracture, reservoir filling judgment and combination of the communication characteristics.
9. The method for quantitatively characterizing the fractured-fluid reservoir according to claim 1, wherein the method for fusing the different types of reservoir property models is specifically as follows: assigning values to the same position condition; the method for fusing the external contour model and the internal reservoir distribution characteristics specifically comprises the following steps: a method in which a reservoir predominates, non-reservoir assignment is a matrix.
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| CN112731527B (en) * | 2019-10-14 | 2024-06-18 | 中国石油化工股份有限公司 | Method and device for enhancing broken solution characteristics based on multi-attribute research |
| US11143771B2 (en) | 2019-10-17 | 2021-10-12 | Saudi Arabian Oil Company | Dolomite mapping using multiscale fracture characterization |
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| CN113447979B (en) * | 2020-03-26 | 2023-11-17 | 中国石油化工股份有限公司 | Identification method of fracture development area and characterization method of fracture |
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| CN111399048B (en) * | 2020-04-29 | 2020-12-08 | 四川杰瑞泰克科技有限公司 | Method for calculating correlation attribute and data weighted reconstruction of broken solution |
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