CN114969870B - Quantitative characterization method for communication sand bodies of any two wells of sandstone reservoir - Google Patents
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Abstract
The invention relates to the technical field of geological analysis of oil and gas field reservoirs, in particular to a quantitative characterization method of any two-well communicated sand bodies of a sand reservoir. The method comprises the following steps: simulating by using a truncated Gaussian simulation method to obtain a sub-phase model, and characterizing the vertical reservoir spread form; step two, simulating uphole data of each lithofacies in the sub-facies model by adopting a random simulation method, and establishing a lithofacies model; thirdly, adopting phase control modeling constraint, and simulating physical parameters through rock phase control; step four, calculating a physical property lower limit to obtain an NTG model; and fifthly, calculating a sand body communicated with the wells based on the NTG model, and realizing the characterization of the connectivity of the sand body connected with any two wells. The method can more accurately describe the plane spreading and spatial distribution conditions of the inter-well communication sand bodies, and realize quantitative description and characterization of connectivity between any two wells.
Description
Technical Field
The invention relates to the technical field of geological analysis of oil and gas field reservoirs, in particular to a quantitative characterization method of any two-well communicated sand bodies of a sand reservoir.
Background
The connectivity of the lithologic oil reservoir is mainly affected by deposition, a correct contrast mode is required to be established for analyzing the sand connectivity relationship among wells, and the analysis of qualitative characterization of the underground multiple sets of sand connectivity relationship has important theoretical and practical significance for deepening reservoir geological research, optimizing well patterns and adjusting residual oil mining.
When the sand connectivity modeling is carried out, PETREL modeling software is mainly used for establishing a connectivity model capable of representing the reservoir sand connectivity on the basis of a basic model such as a construction model, a lithofacies model, an attribute model, an NTG model and the like.
Chinese patent No. CN107330578B discloses a sand connectivity evaluation method, which comprises the following steps: respectively establishing a transverse connectivity sand body sample, a longitudinal connectivity sand body sample and an internal connectivity sand body sample of a work area, and dividing each type of sand body sample into a training sample and a testing sample; training a training sample of each type of sand body sample by using a preset machine learning algorithm, and establishing a corresponding sand body connectivity prediction model; optimizing the corresponding sand body connectivity prediction model according to the test sample of each type of sand body sample so as to enable the prediction result of the corresponding sand body connectivity prediction model to meet the preset condition; and carrying out sand connectivity evaluation on the sand data corresponding to the sand to be identified in the work area according to the optimized sand connectivity prediction model to obtain an evaluation result.
Chinese patent application CN108090656a discloses a method for determining connectivity of sand bodies, which provides first geological parameter information of a first single sand body and second geological parameter information of a second single sand body in a target work area, and a plurality of standard indexes corresponding to designated connectivity levels; the method comprises the following steps: determining membership relations between each standard index and each appointed connectivity grade respectively; setting a weight matrix corresponding to the standard index according to the standard index, and respectively determining target weight values of all the standard indexes in the weight matrix; determining a target index and a target index parameter value according to the first geological parameter information and the second geological parameter information, and determining the sand connectivity between the first single sand body and the second single sand body according to the target index parameter value, the target weight value of the standard index and the membership relation.
In the existing connectivity model research, the communication sand bodies of any two wells represented by the model generally only meet the requirement of the sand bodies communicated with one of any two wells, the number of the sand bodies is numerous, the change is rapid, and the sand bodies can be used as a communication body only by being connected with one well, so that the real inter-well communication sand bodies communicated with any two wells cannot be represented.
Disclosure of Invention
The invention mainly aims to provide a quantitative characterization method for any two-well communication sand bodies of a sandstone reservoir, by adopting the method, the quantitative characterization of any two-well communication sand bodies of the sandstone reservoir can be realized, and the defects of the prior art are overcome.
In order to achieve the above purpose, the present invention adopts the following technical scheme:
the invention provides a quantitative characterization method of a communication sand body of any two wells of a conglomerate reservoir, which comprises the following steps:
simulating by using a truncated Gaussian simulation method to obtain a sub-phase model, and characterizing the vertical reservoir spread form;
Step two, simulating uphole data of each lithofacies in the sub-facies model by adopting a random simulation method, and establishing a lithofacies model;
thirdly, adopting phase control modeling constraint, and simulating physical parameters through rock phase control;
Step four, calculating a physical property lower limit to obtain an NTG model;
And fifthly, calculating a sand body communicated with the wells based on the NTG model, and realizing the characterization of the connectivity of the sand body connected with any two wells.
Further, in the first step of the hierarchical modeling strategy, discrete logging curves of different subphases corresponding to each well in the vertical direction are established through subphase distribution plan diagrams of each period, a corresponding subphase model is established through a truncated Gaussian simulation method, and the model results respect the actual layout form of each subphase of each period in the vertical direction and are characterized.
Further, in the second step of the hierarchical modeling strategy, on the basis of the sub-phase model in the first step, the uphole data are simulated by adopting a random simulation method in each sub-phase, and a lithofacies model corresponding to the uphole data is built.
Furthermore, a multi-level modeling method is adopted, and through sub-phase space position constraint of each period of the sub-phase model, each lithofacies in the sub-phase model is simulated by adopting a sequential indication simulation method, the uphole lithofacies data is simulated, and a corresponding lithofacies model is established.
Further, in the third step, a lithofacies model phase control constraint simulation physical parameter established by a multi-level modeling method is adopted, and a porosity model is obtained through lithofacies model constraint simulation; and adopting rock phase control modeling constraint, and obtaining a permeability model by cooperative simulation of the porosity model.
Further, in the fourth step, four methods of forward and reverse accumulation method, pore structure method, electric lower limit reverse algorithm and oil test verification are utilized to comprehensively select values of physical property standards: the lower limit of the porosity is 5.3%, and the lower limit of the permeability is 0.7mD.
Further, an NTG model is obtained through attribute lower limit value calculation, and the model is divided into an effective reservoir and an ineffective reservoir.
Further, the fifth step specifically includes: calculating a communication sand body communicated with the well; calculating the sand body communicating body under the prior art condition; and constructing a communicated sand body model of any two wells.
Further, in order to characterize the connectivity of the reservoir sand body, a discrete model template is firstly established, an NTG model is assigned to the discrete model, and the reservoir result is divided into an invalid reservoir and an effective reservoir; sand connectivity is calculated in the active reservoir.
Furthermore, sand bodies which are only communicated with a single well in any two wells are removed by using a calculation formula C=B- [ (A+B) -A ]; wherein C is the communicating sand body of any two wells A, B, A is the sand body communicated with any A well, B is the sand body communicated with any B well, and A+B is the sand body communicated with the well in any two wells A, B.
Compared with the prior art, the invention has the following advantages:
According to the method, a hierarchical modeling strategy is adopted, a truncated Gaussian simulation method is utilized to characterize real layout forms of sub-phases in each period in the vertical direction, and a random simulation method is utilized to simulate the interior of each sub-phase on the basis of the sub-phase model to obtain a lithofacies model; and calculating the sand bodies communicated with the wells in any two wells under the prior art condition through calculation formulas, so as to obtain the communicated sand bodies of any two wells, eliminating the sand bodies which are only communicated with a single well in any two wells, and more accurately describing the plane spread and the space distribution condition of the communicated sand bodies between the wells, thereby realizing quantitative characterization and characterization of the connectivity between any two wells.
Drawings
The accompanying drawings, which are included to provide a further understanding of the invention and are incorporated in and constitute a part of this specification, illustrate embodiments of the invention and together with the description serve to explain the invention.
FIG. 1 is a flow chart of a method for quantitatively characterizing any two-well connected sand body of a conglomerate reservoir according to an embodiment of the present invention;
FIG. 2 is a schematic diagram of a communication sand pattern in any two wells in communication with a well under prior art conditions;
FIG. 3 is a graph showing the distribution of sub-planar phases at different phases;
FIG. 4 is a cross-sectional view of a subphase model and a model in the near-north direction obtained by a truncated Gaussian simulation method;
FIG. 5 is a lithofacies model diagram and a near-north cross-sectional view obtained by simulating uphole data inside a subphase model by a random simulation method;
FIG. 6 is a schematic representation of a porosity model obtained by using a lithofacies model control constraint simulation;
FIG. 7 is a schematic diagram of a permeability model obtained by collaborative simulation of lithofacies model control constraints and porosity;
FIG. 8 is a diagram showing an NTG model obtained by calculating the physical property lower limit value;
FIG. 9 is a schematic illustration of a connected sand model in communication with a Y229X3 well;
FIG. 10 is a schematic illustration of a connected sand model in communication with a Y229X5 well;
FIG. 11 is a schematic diagram of a connected sand model of any two wells Y229X3, Y229X5 in a reservoir connected to well communication mode.
Detailed Description
It should be noted that the following detailed description is exemplary and is intended to provide further explanation of the invention. Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention belongs.
It is noted that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of exemplary embodiments according to the present invention. As used herein, the singular forms also are intended to include the plural forms unless the context clearly indicates otherwise, and furthermore, it should be understood that when the terms "comprises" and/or "comprising" are used in this specification, they specify the presence of stated features, steps, operations, and/or combinations thereof.
In order to enable those skilled in the art to more clearly understand the technical scheme of the present invention, the technical scheme of the present invention will be described in detail with reference to specific embodiments.
Examples
FIG. 2 is a schematic diagram of a pattern of communicating sand bodies with wells in any two wells Y229X3, Y229X5 under prior art conditions, wherein the communicating sand bodies comprise sand bodies with Y229X3 wells and sand bodies with Y229X5 wells, and the sand bodies with only the two wells cannot be characterized.
As shown in fig. 1, the quantitative characterization method of the connected sand bodies of any two wells of the sandstone reservoir uses PETREL modeling software, which comprises the following steps:
step one, adopting a hierarchical modeling strategy, simulating to obtain a sub-phase model by using a truncated Gaussian simulation method, and representing the vertical reservoir spread form:
According to geological research, the distribution mode of the planar subphases is shown in fig. 3: the different sub-phase plane distribution modes are shown in fig. 3a, 3b and 3 c. Wherein, fig. 3a is a sub-planar sub-phase diagram of phase 6, the scale and range of the advantageous region in the fan are minimum, in fig. 3b, the sub-planar sub-phase diagram of phase 7 reflects the maximum scale and range of the advantageous region in the obtained fan, and in fig. 3c, the sub-planar sub-phase diagram of phase 8, the distribution range of the fan root is maximum. Fig. 4 is a cross-sectional view of a subphase model and a model in the near north-south direction, simulated by a truncated gaussian simulation method. Based on the previous research results and plane subphase diagrams, a subphase model of a research area is firstly established by adopting a hierarchical modeling strategy, discrete logging curves of different subphases corresponding to each well in the vertical direction are established through subphase distribution plane diagrams of each period, the corresponding subphase model is established by utilizing a truncated Gaussian simulation method, the model results respect the true spreading form of each subphase in each period in the vertical direction and are characterized, and the simulation results are different from the traditional method: different from the fact that the rock phase boundaries of the sub-phases obtained by simulation in the conventional method are at the same position, simulation results of different sub-phases in the vertical direction in each period are constrained by a planar sub-phase diagram, the positions of the different sub-phase boundaries in each period are different, as shown in fig. 4a, a sub-phase model which is more respecting to the geological rule and accords with the underground real oil reservoir internal structure is built, and a near-north-south cross section diagram corresponding to the sub-phase model is built, as shown in fig. 4 b.
Step two, simulating uphole data of each lithofacies in the sub-facies model by adopting a random simulation method, and establishing a lithofacies model:
FIG. 5 is a schematic view of a lithofacies model obtained by simulating uphole data using a stochastic simulation method inside a subfacies model. By adopting a multi-level modeling method, through sub-phase space position constraint of each period of the sub-phase model and sequential indication simulation of each lithofacies in the sub-phase model, uphole lithofacies data are simulated, a corresponding lithofacies model is built as shown in fig. 5a, and a model corresponding to the lithofacies model is in a near-north-south cross section as shown in fig. 5 b.
Step three, adopting phase control modeling constraint, and simulating physical parameters through phase control:
Fig. 6 is a schematic diagram of a porosity model obtained by using a lithofacies model control constraint simulation, and fig. 7 is a schematic diagram of a permeability model obtained by using a lithofacies model control constraint and porosity collaborative simulation. The lithofacies model phase control constraint simulation physical parameters established by the multi-level modeling method are adopted, the porosity model is obtained through lithofacies model constraint simulation, as shown in fig. 6, and similarly, the permeability model is obtained through lithofacies model modeling constraint and porosity model collaborative simulation, as shown in fig. 7.
Step four, calculating a physical property lower limit to obtain an NTG model:
Fig. 8 is a schematic diagram of an NTG model obtained by calculating the physical property lower limit value. Based on the previous study, four methods of forward and reverse accumulation method, pore structure method, electric lower limit reverse algorithm, oil test verification are utilized to comprehensively select values of physical property standards: the lower limit of the porosity is 5.3%, the lower limit of the permeability is 0.7mD, an NTG model is obtained through calculation of the lower limit of the attribute, and the model is divided into an effective reservoir (1) and an ineffective reservoir (0), as shown in FIG. 8.
And fifthly, calculating a sand body communicating body communicated with the wells based on the NTG model, and realizing a sand body connectivity characterization method for connecting any two wells.
Fig. 9 is a schematic diagram of a connected sand model in communication with a Y229X3 well, fig. 10 is a schematic diagram of a connected sand model in communication with a Y229X5 well, and fig. 11 is a schematic diagram of a connected sand model in a reservoir connected and well communication mode and Y229X3 and Y229X5 of any two wells. In order to characterize the sand connectivity of a reservoir, a discrete model template is firstly established, an NTG model is assigned to the discrete model, the reservoir result is divided into an invalid reservoir (0) and an effective reservoir (1), and the sand connectivity between any two wells is characterized in the effective reservoir of the discrete model, so that the sand connectivity only needs to be calculated in the effective reservoir (1). By calculating sand in communication with the Y229X3 well, as shown in fig. 9, with the Y229X5 well, as shown in fig. 10, and with both Y229X3 and Y229X5 wells, as shown in fig. 2, however, the calculated sand results in communication with both Y229X3 and Y229X5 wells are simply a superposition of the results of the two well communication sand alone and cannot result in a result in communication with only both wells. On the basis, a calculation formula C=B- [ (A+B) -A ] is utilized, wherein C is a sand body communicated with any two wells A, B, A is a sand body communicated with any A well, B is a sand body communicated with any B well, A+B is a sand body communicated with a well in any two wells A, B, as shown in fig. 11a, the sand bodies communicated with only two wells Y229X3 and Y229X5 are calculated, and the sand bodies communicated with only a single well in any two wells are removed, as shown in fig. 11B, so that the problem of characterization of the sand bodies communicated with any two wells of a sandstone reservoir is solved, and quantitative characterization and characterization of inter-well connectivity are realized.
According to the method, the well-to-well communication sand bodies can be represented in the geological model, a hierarchical modeling strategy is adopted, the actual spreading form of sub-phases in each period in the vertical direction is represented by using a truncated Gaussian simulation method, and a rock phase model is obtained by simulating the interior of each sub-phase by using a random simulation method on the basis of the sub-phase model; and calculating the sand bodies communicated with the wells in any two wells under the prior art condition through calculation formulas, so as to obtain the communicated sand bodies of any two wells, remove the sand bodies communicated with only a single well in any two wells, more accurately describe the plane spreading and the space distribution conditions of the communicated sand bodies between the wells, and realize quantitative depiction and characterization of the connectivity between the wells.
The above examples are preferred embodiments of the present invention, but the embodiments of the present invention are not limited to the above examples, and any other changes, modifications, substitutions, combinations, and simplifications that do not depart from the spirit and principle of the present invention should be made in the equivalent manner, and the embodiments are included in the protection scope of the present invention.
Claims (3)
1. The quantitative characterization method of the communication sand body of any two wells of the sandstone reservoir is characterized by comprising the following steps of:
simulating by using a truncated Gaussian simulation method to obtain a sub-phase model, and characterizing the vertical reservoir spread form;
Step two, simulating uphole data of each lithofacies in the sub-facies model by adopting a random simulation method, and establishing a lithofacies model;
thirdly, adopting phase control modeling constraint, and simulating physical parameters through rock phase control;
Step four, calculating a physical property lower limit to obtain an NTG model;
calculating sand bodies communicated with the wells based on the NTG model, and realizing the characterization of the connectivity of the sand bodies connected with any two wells;
In the first step of a hierarchical modeling strategy, a discrete logging curve of each well corresponding to different subphases in the vertical direction is established through a subphase distribution plan of each period, a corresponding subphase model is established by adopting a truncated Gaussian simulation method, and the model result vertically respects the true spreading form of each subphase of each period and characterizes the true spreading form;
In the second step, adopting a hierarchical modeling strategy, simulating uphole data in each subphase by adopting a random simulation method on the basis of the subphase model in the first step, and establishing a lithofacies model corresponding to the uphole data;
Adopting a multi-level modeling method, simulating uphole lithofacies data by adopting a sequential indication simulation method through sub-facies space position constraint of sub-facies models in each period and each lithofacies in the sub-facies model, and establishing a corresponding lithofacies model;
In the third step, a lithofacies model phase control constraint simulation physical parameter established by a multi-level modeling method is adopted, and a porosity model is obtained through lithofacies model constraint simulation; adopting rock phase control modeling constraint, and obtaining a permeability model by cooperative simulation of a porosity model;
In the fourth step, four methods of positive and negative accumulation method, pore structure method, electric lower limit inverse algorithm and oil test verification are utilized to comprehensively select values of physical property standards: the lower limit of the porosity is 5.3 percent, and the lower limit of the permeability is 0.7mD;
The fifth step specifically comprises: calculating a communication sand body communicated with the well; calculating the sand body communicating body under the prior art condition; constructing a communication sand body model of any two wells;
In order to characterize the connectivity of the reservoir sand, firstly, a discrete model template is established, an NTG model is assigned to the discrete model, and the reservoir result is divided into an invalid reservoir and an effective reservoir; sand connectivity is calculated in the active reservoir.
2. The method of claim 1, wherein the NTG model is calculated from a lower value of the attribute and is divided into an active reservoir and an inactive reservoir.
3. The method of claim 1, wherein sand communicated only with a single well in any two wells is removed by using a calculation formula C = B- [ (a+b) -a ]; wherein C is the communicating sand body of any two wells A, B, A is the sand body communicated with any A well, B is the sand body communicated with any B well, and A+B is the sand body communicated with the well in any two wells A, B.
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| CA2054964A1 (en) * | 1991-02-22 | 1992-08-23 | Charles H. Stewart | Method for exploring for hydrocarbons utilizing three dimensional modeling of thermal anomalies |
| CN104809277A (en) * | 2015-04-14 | 2015-07-29 | 中国石油天然气股份有限公司 | Geological modeling method for horizontal well of ultra-low permeability tight reservoir |
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| CN110566196B (en) * | 2019-10-08 | 2022-05-24 | 岭南师范学院 | Reservoir connectivity analysis method |
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| CA2054964A1 (en) * | 1991-02-22 | 1992-08-23 | Charles H. Stewart | Method for exploring for hydrocarbons utilizing three dimensional modeling of thermal anomalies |
| CN104809277A (en) * | 2015-04-14 | 2015-07-29 | 中国石油天然气股份有限公司 | Geological modeling method for horizontal well of ultra-low permeability tight reservoir |
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