CN110705000A - Unconventional reservoir stratum encrypted well fracturing dynamic micro-seismic event barrier region determination method - Google Patents
Unconventional reservoir stratum encrypted well fracturing dynamic micro-seismic event barrier region determination method Download PDFInfo
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Abstract
The invention discloses a method for determining a fractured dynamic micro-seismic event barrier region of an unconventional reservoir encryption well, which comprises the following steps of: s1, establishing a three-dimensional geological model with physical and geomechanical parameters; s2, establishing a natural fracture network model by combining indoor core-logging-seismic monitoring; s3, calculating the hydraulic fracturing complex fractures of the early-stage production well; s4, establishing a shale gas reservoir model and calculating a current pore pressure field; s5, establishing a dynamic geomechanical model and calculating a dynamic ground stress field; s6, calculating horizontal fracturing complex fractures of the encrypted well at different production times based on the early complex fractures and the current ground stress field; and S7, analyzing the micro-seismic event barrier area of the fractured encrypted well and the dynamic change of the micro-seismic event barrier area of the fractured encrypted well. The invention has the beneficial effects that: the method can accurately reflect the influence of the exploitation of the shale reservoir with the developed cracks on the fracturing of the encrypted well, determine the dynamic change of the barrier effect of the microseism event in the exploitation process, and provide a reliable basis for the optimization of the encryption opportunity and the fracturing construction parameters.
Description
Technical Field
The invention relates to the field of oil and gas resource development and yield increase transformation thereof, in particular to a method for determining a fractured dynamic micro-seismic event barrier region of an unconventional reservoir encryption well.
Background
The microseismic event "barrier effect" is defined as: the distribution situation of the micro-seismic events near the well periphery of the encrypted well is similar to that of the old well, but the magnitude and the quantity of the micro-seismic events are obviously weakened when the micro-seismic events are near the early-stage production well, even the micro-seismic events are not detected, and the phenomenon is called as the barrier effect of the micro-seismic events; in correspondence with the "barrier effect" of a microseismic event, the area near the earlier producer wells is referred to as the "barrier zone" of the microseismic event.
With the continuous exploitation of shale gas resources, a plurality of shale gas reservoirs in China are gradually entering the middle stage of development. In the middle-term development and adjustment scheme, the block capacity needs to be supplemented, the unused area needs to be fully developed and the recovery ratio needs to be improved in a mode of drilling a densified horizontal well in the current mining area and implementing large-displacement volume fracturing. The shale gas reservoir entering the middle stage of development starts to implement volume fracturing of the encrypted test well step by step, and the micro-seismic monitoring is carried out on the fracturing construction process of the encrypted test well to discover that: the condition of the micro-seismic events around the well of the encrypted well is similar to that of the fracturing of the early-stage production well, namely a large number of micro-seismic events with different seismic levels appear, which indicates that complex fractures are generated in the fracturing of the area; however, as one moves further from the infill well and closer to the earlier producer well, there will be a significant reduction in the magnitude and number of microseismic events, even if no microseismic events are detected, indicating that no complex fractures are formed in the area away from the infill well and closer to the earlier producer well. This phenomenon, which is also detected when the previous producer well fractures, appears to be a barrier that blocks microseismic events outside of the area near the previous producer well, and is therefore referred to as the microseismic event "barrier effect" and the area near the previous producer well as the microseismic event "barrier zone". Due to the formation of the micro-seismic event barrier effect, the fracturing transformation effect of the encrypted well is not as good as that of the original production well. Since the extent of commercial exploitation of shale gas by subsurface seepage mainly depends on complex fractures formed by volume fracturing, the 'barrier effect' of a microseismic event greatly limits the single well productivity of an infilled well. In order to determine the favorable time of fracturing of the encrypted well and provide reliable basis for the design of volume fracturing construction parameters, the micro-seismic event barrier zone and the dynamic change thereof need to be determined.
The micro-seismic event monitoring results when the earlier-stage production well is fractured and the micro-seismic event monitoring results when the well is fractured are encrypted are compared, and the following can be found: the shale reservoir has a gentle structure and weak heterogeneity, the early-stage production well and the encrypted well are in the same region, and the difference between the fracturing stratum condition of the encrypted well and the early-stage production well mainly comes from the fact that the geomechanical characteristics (particularly pore pressure and ground stress) of the reservoir are changed due to long-term exploitation of the early-stage production well, so that the dynamic change of the geomechanical characteristics before encryption needs to be analyzed and obtained, the fracture morphology of the encrypted well is analyzed and calculated at different production time, the cause of the barrier effect of the micro-seismic event is revealed, the dynamic change condition of the barrier region of the micro-seismic event is finally determined, and reliable basis is provided for determination of the favorable time for fracturing of the encrypted well and design of volume fracturing construction parameters.
Disclosure of Invention
The invention aims to overcome the defects of the prior art and provides a shale gas reservoir fracturing dynamic micro seismic event barrier area determination method which can simulate and analyze shale gas and calculate a complicated fracture of a fracturing well volume under the condition of geomechanical parameter field change in different production periods.
The purpose of the invention is realized by the following technical scheme: the unconventional reservoir encryption well fracturing dynamic micro seismic event barrier zone determination method comprises the following steps:
s1, establishing a three-dimensional geological model with physical and geomechanical parameters, wherein the layer position information in the three-dimensional geological model is matched with the real stratum position, the physical parameters at least comprise porosity, permeability, saturation and sedimentary facies, and the geomechanical parameters at least comprise Young modulus, Poisson ratio, lithology, lithofacies and three-dimensional ground stress.
S2, identifying the micro natural fracture parameters through core analysis, obtaining the three-dimensional shape and distribution of the fractures around the well through imaging logging data analysis, obtaining the natural fracture distribution of the reservoir through seismic interpretation result analysis, and finally integrating the core-logging-seismic data to establish a natural fracture network model.
And S3, embedding the natural fracture network model into the three-dimensional geological model, and calculating and generating the hydraulic fracture complex fracture of the early-stage production well by combining hydraulic fracture design and construction data.
S4, embedding the complex cracks of the hydraulic cracks of the early-stage production well into a geological model with natural cracks, establishing a three-dimensional shale gas reservoir model according to the three-dimensional geological model, and analyzing and calculating the change of the pore pressure field of the reservoir at different periods by using production dynamic parameters.
S5, establishing a four-dimensional dynamic ground stress model with reservoir physical properties and rock mechanical properties by using the three-dimensional geological model, and analyzing and calculating the dynamic ground stress evolution condition of the reservoir according to the change result of the pore pressure field.
And S6, respectively combining the geostress results of different early-stage production wells at the production time with the complex fracture network geological model, and calculating the volume fracture complex fractures of the encrypted wells at the production time of different early-stage production wells by combining the design and construction data of the volume fracture of the encrypted wells on the basis of the complex fracture network geological model with the updated geomechanical parameters.
And S7, comparing the horizontal stress difference under different production time with the complex fracture distribution condition of the encrypted well, and determining the micro-seismic time barrier area and the dynamic change process thereof.
Further, the S7 includes the following four steps:
s7 (I) obtaining the horizontal stress difference after a certain time of production through the dynamic ground stress calculation result;
s7 (II) fracturing complex fracture distribution and geometric parameters through the produced encrypted well volume;
s7 (III) based on the fact that complex cracks are not easy to generate when the horizontal stress difference is larger, comparing the horizontal stress difference after a certain period of production with the complex crack distribution condition of the encryption well, and determining an area with a micro-seismic event barrier effect, wherein the boundary of the barrier area is a position which is close to the encryption well and changes the crack complexity;
s7 (IV) comparing the horizontal stress difference under a plurality of different production times with the complex fracture distribution condition of the encrypted well, determining a corresponding micro seismic event barrier area, and finally forming a dynamic change process of the micro seismic event barrier area.
The invention has the following advantages:
(1) according to the invention, a shale reservoir gas reservoir model with a complex fracture network is established through reservoir natural fracture description and early stage fracturing complex fracture analysis, and the problems that only simple fracturing fractures can be described in the traditional shale reservoir gas reservoir model, and the dynamic change of pore pressure in the production process cannot be accurately analyzed are solved;
(2) according to the method, the production dynamic parameters are considered, the shale reservoir four-dimensional dynamic ground stress model is established, and the problem that the three-dimensional static ground stress model cannot reflect the dynamic change of the ground stress field in the long-term exploitation process of the shale reservoir is solved;
(3) the method can accurately describe the natural fracture state of the shale reservoir, the early-stage hydraulic fracturing fracture state and the heterogeneity and anisotropy of the pore elastic parameters, and can reflect the real state of the shale reservoir before fracturing of the infilled well to a greater extent;
(4) the invention is based on the four-dimensional dynamic geostress result developed encrypted well volume fracturing analysis, and solves the problem that the complex fracture morphology of the encrypted well is not clear;
(5) the invention provides a method for determining a shale gas reservoir encrypted well volume fracturing micro-seismic event barrier area, which provides a reliable basis for determining the favorable time of shale gas encrypted well fracturing construction and optimizing the design of construction parameters, thereby being favorable for maximizing the single well productivity of an encrypted well.
Drawings
FIG. 1 is a flow chart of the present invention;
FIG. 2 is a diagram of a reservoir natural fracture network model obtained by comprehensive core-logging-seismic data analysis;
FIG. 3 is a comparison verification diagram of early-stage production well construction microseismic monitoring results and simulated volume fracturing complex fractures;
FIG. 4 is a graph of pore pressure history fit results before fracturing of a cased hole;
FIG. 5 is a diagram of the results of a geometric inversion of a reservoir;
FIG. 6 is a graph comparing initial minimum level principal stress with post-production minimum level principal stress;
FIG. 7 is a verification diagram for comparing a microseismic monitoring result of encrypted well construction with a simulated volume fracturing complex fracture;
FIG. 8 is a graph comparing horizontal stress differences and complex fracture distributions of the infilled well at different production times;
FIG. 9 is a final determination of the microseismic event barrier zone and its dynamic boundaries.
Detailed Description
The invention will be further described with reference to the accompanying drawings, but the scope of the invention is not limited to the following.
The unconventional reservoir encryption well fracturing dynamic micro seismic event barrier zone determination method comprises the following steps:
s1, establishing a three-dimensional geological model with physical and geomechanical parameters, wherein the layer position information in the three-dimensional geological model is matched with the real stratum position, the physical parameters at least comprise porosity, permeability, saturation and sedimentary facies, and the geomechanical parameters at least comprise Young modulus, Poisson ratio, lithology, lithofacies and three-dimensional ground stress;
the specific steps for establishing the three-dimensional geological model are as follows: firstly, establishing a three-dimensional geological stratum model of each small layer in a storage layer according to seismic data or a geological atlas, and correcting stratum information by using single-well data in a block; then dividing plane grids according to the calculation precision requirement, and dividing the grids in the longitudinal direction by the thickness of the small layer; then, the data of a single well parameter profile (at least comprising porosity, permeability, saturation, sedimentary facies, density, Young modulus, Poisson ratio, lithology, lithofacies and three-dimensional ground stress) are explained by combining with the logging corrected by the indoor core experiment to interpolate the reservoir stratum, finally, the physical property and geomechanical property parameters are subjected to three-dimensional interpolation to generate a three-dimensional geological model, the sedimentary facies and the lithofacies are constrained for the porosity, permeability, saturation physical property parameters, Young modulus and Poisson ratio petrophysical property parameters, and Gaussian random function model interpolation is utilized; and for the three-direction main stress parameters, performing interpolation by using a Kriging linear interpolation method.
S2, identifying microscopic natural fracture parameters through core analysis, obtaining three-dimensional morphology and distribution of fractures around a well through imaging logging data analysis, obtaining natural fracture distribution of a reservoir through seismic interpretation result analysis, and finally establishing a natural fracture network model by integrating core-logging-seismic data, wherein the specific establishment process comprises the following five steps:
s2 (I) researching the distribution condition of the multi-scale natural cracks of the rock core through rock core observation, well logging information, slice observation and scanning electron microscope test and analysis, and counting the form, size and density parameters of the microcracks;
s2 (II) obtaining three-dimensional distribution, inclination angle, trend, space density and size of the crack around the well through imaging logging data analysis;
s2 (III) obtaining the three-dimensional distribution condition of natural fractures of the reservoir through seismic interpretation result analysis, generating a natural fracture network in a three-dimensional space by combining a core analysis result and a well periphery fracture analysis result based on imaging logging information, and distinguishing and counting the sizes and distribution states of different types of natural fractures as shown in figure 2;
s2 (IV) combining the core-imaging logging analysis results in S2 (I) and S2 (II) and the sizes and distribution states of different types of natural fractures in the step S2 (III), and carrying out attribute assignment on fracture opening and permeability parameters including three-dimensional fractures;
s2 (V) embedding the natural fracture network model into the grid of the three-dimensional geological model. For natural fractures embedded into the grids, the fracture attributes are calculated by combining the rock core-imaging logging analysis results (including different types of fracture openness and permeability), the equivalent permeability and porosity of the fracture grids are calculated, and fracture form factors are calculated by combining the fracture density degree on the unit grids and utilizing the fracture intervals in the unit grids.
And S3, embedding the natural fracture network model into the three-dimensional geological model, and calculating and generating the hydraulic fracture complex fracture of the early-stage production well by combining hydraulic fracture design and construction data. The specific calculation process comprises the following four steps;
s3 (I) analyzing and counting the design and construction parameters of the previous fracturing well of the research block, wherein the parameters comprise fracturing interval, perforating cluster length, fracturing fluid quantity, pumping pressure and displacement;
s3 (II) setting fracturing segment data and perforation data in each early-stage production well of the research block, and recording an actual pumping program and construction parameters;
s3 (III) fitting and calculating the volume fracturing complex cracks of the early-stage production well in a three-dimensional geological model with a natural crack network, finally forming a three-dimensional geological model with a complex crack network, and analyzing the volume fracturing complex crack form and the influence of natural cracks on the complex crack formation;
s3 (IV) carrying out comparative verification on the volume fracture complex fracture by using the microseism monitoring result, as shown in figure 3.
S4, embedding complex cracks of hydraulic fractures of the previous production well into a geological model with natural fractures, establishing a three-dimensional shale gas reservoir model according to the three-dimensional geological model, and analyzing and calculating changes of reservoir pore pressure fields in different periods by using production dynamic parameters, wherein the specific calculation process comprises the following three steps;
s4 (I) leading a three-dimensional geological model with a complex fracture network (including natural fractures and hydraulic fractures) into a reservoir simulator, establishing a three-dimensional shale gas reservoir model of a finite difference grid, and simultaneously considering the physical property of a reservoir matrix, the permeability anisotropy of the complex fractures, the porosity and the fracture form factor attribute in the model;
s4 (II) establishing a double-hole seepage and seepage mechanism in the three-dimensional shale gas reservoir model, setting a shale desorption model and a phase seepage model according to an indoor core experiment result, and establishing a vertical pipe flow model according to a well testing analysis result;
s4 (III) performs history fitting in the three-dimensional shale gas reservoir model in combination with production dynamic data of a single well at different locations over a certain period of time (the specified time may be determined according to actual requirements of site engineering, and may be different times within a time period of several days, months, or years of production), and calculates three-dimensional pore pressure fields at different production times, as shown in fig. 4.
S5, establishing a four-dimensional dynamic ground stress model with reservoir physical properties and rock mechanical properties by using the three-dimensional geological model, and analyzing and calculating the evolution situation of reservoir dynamic geomechanical parameters (such as ground stress) according to the change result of the pore pressure field. The specific calculation process comprises the following five steps;
s5 (I) according to the geological model node parameters, performing the reservoir geometrical information of the research block reversely and establishing a geometrical entity, as shown in FIG. 5;
s5 (II) selecting unit types according to the requirement of reservoir layering and dividing grids to establish a finite element geomechanical grid model;
s5 (III) compiling a three-dimensional search interpolation program, interpolating attributes in the three-dimensional geological model into a finite element geomechanical grid model, and establishing a three-dimensional isotropic geomechanical model;
s5 (IV) establishing a shale transverse isotropy geomechanical model by combining the anisotropy and the stress sensitivity parameters;
and S5 (V) calculating and analyzing the evolution situation of the dynamic geomechanical parameters (particularly the magnitude and the direction of the geostress) of the reservoir by taking the dynamic pore pressure field obtained by history fitting as a boundary condition, as shown in FIG. 6.
S6, updating the dynamic geomechanical parameter (such as ground stress) evolution result to the related geomechanical parameter in the original geological model with the complex fracture network, and on the basis, calculating the complex fracture of the volume fracture of the encrypted well by combining the design/construction data of the volume fracture of the encrypted well, wherein the specific calculation process comprises the following three steps:
s6 (I) utilizing a three-dimensional search interpolation program to interpolate a dynamic geomechanical parameter (such as ground stress) evolution result obtained by calculating a finite element model into an original geomodel with a complex crack network, and updating related geomechanical parameters;
s6 (II) fitting and calculating a consolidated well volume fracturing complex fracture in a three-dimensional geological model with a complex fracture network (natural fracture and early-stage production well fracturing fracture);
s6 (III) comparing and verifying the complex fracture of the volume fracture by using the microseism monitoring result, as shown in figure 7, comparing the complex fracture with the current three-dimensional ground stress field, and analyzing the influence of the production effect of the early-stage production well on the fracture form of the encrypted well fracture.
S7, comparing the horizontal stress difference under different production time with the complex fracture distribution condition of the encrypted well, and determining a micro-seismic event barrier area and a dynamic change process thereof, wherein the specific analysis process comprises the following four steps:
s7 (I) obtaining the horizontal stress difference after a certain time of production (which can be determined according to the actual demand of the field engineering for a certain time and can be different times within the time period of several days, months or years) through the dynamic stress calculation result;
s7 (II) fracturing complex fracture distribution and geometric parameters through the volume of the encrypted well after a certain production time (the specified time can be determined according to the actual requirements of field engineering and can be different time within the time period of several days, months or years of production);
s7 (III) based on the fact that complex cracks are less likely to be generated when the horizontal stress difference is larger, comparing the horizontal stress difference after a certain time of production (the specified certain time can be determined according to the actual requirements of field engineering and can be different time within a time period of several days or months or years of production) with the complex crack distribution situation of the encryption well, as shown in FIG. 8, if the crack complexity of the compression well is obviously reduced and the horizontal stress difference is obviously increased in a region from a certain position to a region close to a previous production well, determining that the micro-seismic event barrier effect occurs in the region, wherein the boundary of the barrier region is a position close to the encryption well and the crack complexity is changed, as shown in FIG. 9;
s7 (IV) comparing the horizontal stress difference under a plurality of different production times with the complex fracture distribution condition of the encrypted well, determining a corresponding micro seismic event barrier area, and finally forming a dynamic change process of the micro seismic event barrier area.
Therefore, the method for determining the barrier zone of the microseism event can describe the natural fracture distribution and parameters of the shale reservoir, and fit out the volume fracture parameters of the previous production well based on the natural fracture distribution and parameters, so that the change conditions of the crustal stress and the geomechanical parameters at different positions in different production time are simulated and analyzed. On the basis, the complex fractured complex fractures of the encrypted well volume are calculated through fitting, the real dynamic change state of the shale reservoir in the fracturing process of the previous fracturing, production and encrypted wells and the complex fractured form of the encrypted well volume are reflected to a greater extent, the micro-seismic event barrier effect occurring in the fracturing process of the encrypted test well is accurately disclosed, and the key technical problems that the traditional geomechanical model is low in accuracy of describing a natural fracture network, the fractures of the previous production well cannot be accurately reflected in the seepage of the shale reservoir, the three-dimensional static geostress model cannot accurately reflect the geostress and the reservoir parameter change in the fracturing process of the shale gas reservoir, the analysis of the fractured complex fractures of the encrypted well cannot be based on the real geomechanical state and the like of the fractured key technical problems of the fractured shale gas reservoir of the encrypted well are solved.
While the invention has been described above in connection with what is presently considered to be the most practical and preferred embodiment, it is to be understood that the invention is not to be limited to the disclosed embodiment, but on the contrary, is intended to cover various other combinations, modifications, and environments and is capable of changes within the scope of the invention as set forth in the appended claims either as a result of the above teachings or as a result of the knowledge or technology of those skilled in the relevant art. And that modifications and variations may be effected by those skilled in the art without departing from the spirit and scope of the invention as defined by the appended claims.
Claims (2)
1. The method for determining the dynamic micro seismic event barrier zone of the unconventional reservoir encrypted well fracturing is characterized by comprising the following steps of:
s1, establishing a three-dimensional geological model with physical and geomechanical parameters, wherein the layer position information in the three-dimensional geological model is matched with the real stratum position, the physical parameters at least comprise porosity, permeability, saturation and sedimentary facies, and the geomechanical parameters at least comprise Young modulus, Poisson ratio, lithology, lithofacies and three-dimensional ground stress;
s2, identifying microscopic natural fracture parameters through core analysis, obtaining three-dimensional morphology and distribution of fractures around a well through imaging logging data analysis, obtaining natural fracture distribution of a reservoir through seismic interpretation result analysis, and finally integrating core-logging-seismic data to establish a natural fracture network model;
s3, embedding the natural fracture network model into a three-dimensional geological model, and calculating and generating the hydraulic fracture complex fracture of the early-stage production well by combining hydraulic fracture design and construction data;
s4, embedding the complex cracks of the hydraulic fractures of the previous production well into a geological model with natural fractures, establishing a three-dimensional shale gas reservoir model according to the three-dimensional geological model, and analyzing and calculating the change of reservoir pore pressure fields in different periods by using production dynamic parameters;
s5, establishing a four-dimensional dynamic ground stress model with reservoir physical properties and rock mechanical properties by using the three-dimensional geological model, and analyzing and calculating the dynamic ground stress evolution condition of the reservoir according to the change result of the pore pressure field;
s6, respectively combining the geostress results of different early-stage production wells at the production time with the complex fracture network geological model, and calculating the complex fracture of the encrypted well volume fracture at the different early-stage production wells at the production time by combining the design construction data of the volume fracture of the encrypted well on the basis of the complex fracture network geological model with the updated geomechanical parameters;
and S7, comparing the horizontal stress difference under different production time with the complex fracture distribution condition of the encrypted well, and determining the micro-seismic time barrier area and the dynamic change process thereof.
2. The unconventional reservoir infilled well fractured dynamic micro-seismic event barrier zone determination method according to claim 1, characterized in that said S7 comprises the following four steps:
s7 (I) obtaining the horizontal stress difference after a certain time of production through the dynamic ground stress calculation result;
s7 (II) fracturing complex fracture distribution and geometric parameters through the volume of the encrypted well after a certain time;
s7 (III) based on the fact that complex cracks are not easy to generate when the horizontal stress difference is larger, comparing the horizontal stress difference after a certain period of production with the complex crack distribution condition of the encryption well, and determining an area with a micro-seismic event barrier effect, wherein the boundary of the barrier area is a position which is close to the encryption well and changes the crack complexity;
s7 (IV) comparing the horizontal stress difference under a plurality of different production times with the complex fracture distribution condition of the encrypted well, determining a corresponding micro seismic event barrier area, and finally forming a dynamic change process of the micro seismic event barrier area.
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| US16/790,801 US11009620B2 (en) | 2019-07-04 | 2020-02-14 | Method for determining favorable time window of infill well in unconventional oil and gas reservoir |
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