CN116263901A - Shale gas development evaluation method and system - Google Patents
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Abstract
The invention discloses a shale gas development evaluation method and a shale gas development evaluation system, wherein the shale gas development evaluation method comprises the following steps: acquiring static characteristics of the producing area before fracturing of the favorable reservoir according to the favorable reservoir section identification, the reservoir quality classification evaluation and the reservoir spread evaluation; inverting the fracture network parameters after fracturing of the shale gas well based on static characteristics and production dynamic data before fracturing of the favorable reservoir in the production area, and carrying out gas well productivity evaluation and classification evaluation to obtain the characteristics of the reservoir after fracturing; analyzing the connectivity of the reservoir after fracturing by using qualitative and quantitative various technical methods, and determining the optimal development well spacing of the production area; on the basis of the seam network shape analysis, evaluating longitudinal well pattern deployment of the production area; based on the quantitative characterization of shale reservoir stress sensitivity in the production area, a reasonable development mode and real-time production allocation of the gas well are determined. The invention can comprehensively recognize the shale gas, thereby determining the shale gas key development technical policy and realizing the efficient development of the shale gas.
Description
Technical Field
The invention belongs to the technical field of natural gas development, and particularly relates to a shale gas development evaluation method and system.
Background
Shale Gas (shale Gas) refers to unconventional natural Gas which is mainly in adsorption and free state and is endowed in organic shale and interlayer thereof, and has large distribution area, no obvious Gas reservoir boundary, extremely poor reservoir permeability and 10 ground permeability -4 ~10 -6 mD, macroscopically relatively homogeneous, microscopically heterogeneous, and parameters, standards and accuracy of reservoir evaluation performed by seismic data and a small number of exploratory wells in the exploration stage cannot meet the requirements of the development stage. Therefore, in the development stage, establishing quantitative characterization parameters and standards of the reservoir is a basis for identifying shale reservoirs from microcosmic and macroscopic aspects, and evaluating spatial distribution characteristics of different types of reservoirs is a precondition for carrying out fracturing transformation design and development technical policy optimization.
Compared with the conventional gas reservoir, the shale reservoir has the characteristic of self-sealing, and the shale pneumatic utilization concept is different only by forming a complex fracture network through long horizontal well and large-scale volume fracturing, so that the effective development of a single well can be realized. Practice proves that the proper interference among wells and clusters is proper during manual reconstruction, and the horizontal and longitudinal compound flow is proper. The permeability of the sea shale matrix reservoir is extremely low, the reservoir seam is formed, the reservoir is siliceous, carbonaceous and organic matter content is higher, the seam is formed, and the five-peak group-Dragon is developed 1 The seam forming density of the sublevel layer is large and reaches 20-50 pieces/m, and the extension of the height of the hydraulic fracture is directly influencedThe longitudinal movement height is limited, so the matching relation between the hydraulic fracture network parameters and the planar well spacing and the longitudinal well pattern is the key for influencing the longitudinal and transverse reserve movement degree. In addition, the sea shale is distributed in a thin layer shape, belongs to a soft stratum, and is easy to generate stress sensitivity effect due to the development of fracture networks with different scales after fracturing, especially in a microcrack and near-fracture zone matrix area without propping agent, the stress sensitivity is extremely strong, so that the production system is a key for influencing the shale gas extraction degree in a matrix in an SRV area.
Disclosure of Invention
Aiming at the problems, the invention provides a shale gas development evaluation method and a shale gas development evaluation system, which are used for quantitatively recognizing the essential characteristics of a shale gas reservoir, evaluating shale gas production capacity and determining a reasonable shale gas development technical policy.
A shale gas development evaluation method comprises the following steps: acquiring static characteristics of the producing area before fracturing of the favorable reservoir according to the favorable reservoir section identification, the reservoir quality classification evaluation and the reservoir spread evaluation; inverting the fracture network parameters after fracturing of the shale gas well based on static characteristics and production dynamic data before fracturing of the favorable reservoir in the production area, and carrying out gas well productivity evaluation and classification evaluation to obtain the characteristics of the reservoir after fracturing; analyzing the connectivity of the reservoir after fracturing by using qualitative and quantitative various technical methods, and determining the optimal development well spacing of the production area; on the basis of the seam network shape analysis, evaluating longitudinal well pattern deployment of the production area; based on the quantitative characterization of shale reservoir stress sensitivity in the production area, a reasonable development mode and real-time production allocation of the gas well are determined.
Further, according to the favorable layer section identification, the reservoir quality classification evaluation and the reservoir spread evaluation, the method for acquiring the static characteristics of the favorable reservoir in the production area before fracturing comprises the following steps:
obtaining microscopic pore structure characterization and mineral composition of the production area according to geochemical parameters, geophysical parameters and geological comprehensive parameters;
determining shale localization evaluation indexes and classification standards of the favorable layer segments according to the microcosmic pore structure representation and the mineral composition;
comprehensively determining reservoir classification of the production area according to index gas content of a reservoir macroscopic reflection substance foundation and index brittleness index reflecting compressibility;
and determining macroscopic distribution of all main force small layers in the production area on the regional space according to reservoir data, crack number and mechanical data of the well points of the horizontal well, seismic data, mechanical data and fracturing prediction data among the wells.
Further, based on static characteristics and production dynamic data before fracturing of the favorable reservoir in the production area, inverting the fracture network parameters after fracturing of the shale gas well, carrying out gas well productivity evaluation and classification evaluation, and acquiring the characteristics of the reservoir after fracturing comprises the following steps:
inverting apparent parameters of the fractured reservoir according to the well test data, the production dynamic data and various production models of the production area;
determining the probability distribution range of single well productivity according to production dynamic data and the distribution rule of the productivity key characterization parameters in the effective reservoir parameters after fracturing;
and classifying the single wells with the determined productivity according to the gas well classification evaluation standards with benefits as guidance at different stages.
Further, the method for analyzing the connectivity of the reservoir after fracturing by utilizing a plurality of qualitative and quantitative technical methods and determining the optimal development well spacing of the production area comprises the following steps:
determining interference probability according to the relation between the microseism event and the effective stitch length;
determining a communication mode according to the interference well test result;
determining interference intensity according to production dynamic evaluation productivity index change;
based on the interference probability, the communication mode and the interference intensity, optimizing the multi-joint network parameters by taking the single-well productivity index as an objective function and the fracturing scale as a constraint condition, and obtaining the well spacing of the gas well under the condition of maximizing the single-well productivity index;
and (3) taking the multi-well dynamic accumulation yield as an optimization target, taking the total proppant volume as an internal constraint condition, taking the gas well development economy as an external constraint condition, and globally optimizing well spacing and network-sewing parameters.
Further, on the basis of the pattern analysis, the evaluation of the longitudinal well pattern deployment of the production area comprises the following steps:
analyzing shale gas well network parameters by a finite element method to obtain shale gas well network morphology;
based on a hydraulic fracturing physical simulation experiment, on-site tracer dynamic monitoring and gas well production dynamic evaluation results of the target body position at adjacent layers, obtaining longitudinal high-quality small-layer reserve distribution of the gas well;
establishing a star-shaped fracture network section mathematical model according to the fracture network shape of the shale gas well and the longitudinal high-quality small-layer reserves distribution of the gas well;
and evaluating the longitudinal well pattern deployment of the production area according to the star-shaped seam network section mathematical model.
Further, based on the quantitative characterization of shale reservoir stress sensitivity in the production area, determining a reasonable development mode and real-time production allocation of the gas well comprises the following steps:
according to mechanism analysis and core experiments, determining that the shale reservoir stress sensitivity coefficient gamma is a gas well production pressure difference function of a soft stratum, and obtaining a shale permeability stress sensitivity curve;
according to the shale permeability stress sensitivity curve, a shale gas well physical model after fracturing is established, a single-section main fracture is taken as a unit, a bilinear flow mathematical model of gas flowing into the fracture from the stratum and flowing into the shaft from the fracture is established, and a shale gas well instantaneous inflow dynamic curve is obtained by superposing the shale permeability stress sensitivity curve through the yield;
based on the instantaneous inflow dynamic curve of the shale gas well in the production area, the gas well production allocation is comprehensively optimized by combining economic evaluation, and the reasonable development mode and real-time production allocation of the gas well are determined.
Further, the mathematical model of the star-shaped slit net section is specifically as follows:
wherein: y is the vertical distance of the volume element from m; b is the maximum vertical distance of the volume element from the shaft, m; x is the lateral extension length of the crack at a position y from the height of the shaft, m; a is the maximum extension length of the fracture lateral from the position y of the well bore height, m.
Further, the gas well production pressure difference function is specifically as follows:
wherein: gamma is the shale reservoir stress sensitivity coefficient; Δp is the production differential pressure; A. b, C is a constant.
Further, the shale gas well instantaneous inflow dynamic curve is specifically as follows:
wherein: q (Q) g The production of the gas well is m/s; m is the pseudo pressure, P a 2 ;p i 、p wf Respectively the original stratum pressure and the bottom hole flow pressure, P a ;K m 、K f Matrix and fracture system permeability, m 2 ;t a Is the material equilibration time, s; gamma ray m 、γ mi Stress sensitivity coefficients of a certain moment and an original state are respectively obtained; w (w) f 、x f The width and half length of the main fracture zone, m; b is a volume coefficient; mu is the viscosity of the gas at the formation pressure at a certain moment, P a S; h is the effective reservoir thickness, m.
The invention also provides a shale gas development evaluation system, which comprises:
the reservoir static recognition unit before fracturing modification acquires static characteristics of the producing area before fracturing of the favorable reservoir according to favorable reservoir section identification, reservoir quality classification evaluation and reservoir spreading evaluation;
the reservoir dynamic recognizing unit after fracturing modification inverts the fracture network parameters after fracturing of the shale gas well based on static characteristics and production dynamic data before fracturing of the favorable reservoir in the production area, and carries out gas well productivity evaluation and classification evaluation to acquire the characteristics of the reservoir after fracturing;
the plane well spacing evaluation unit is used for analyzing the connectivity of the reservoir after fracturing by utilizing a plurality of qualitative and quantitative technical methods and determining the optimal development well spacing of the production area;
the longitudinal well pattern evaluation unit is used for evaluating the longitudinal well pattern deployment of the production area on the basis of the seam pattern shape analysis;
and the production system evaluation unit is used for determining a reasonable development mode and real-time production allocation of the gas well based on the quantitative characterization of the stress sensitivity of the shale reservoir in the production area.
Further, the reservoir static recognition unit before fracturing modification is specifically used for:
obtaining microscopic pore structure characterization and mineral composition of the production area according to geochemical parameters, geophysical parameters and geological comprehensive parameters;
determining shale localization evaluation indexes and classification standards of the favorable layer segments according to the microcosmic pore structure representation and the mineral composition;
comprehensively determining reservoir classification of the production area according to index gas content of a reservoir macroscopic reflection substance foundation and index brittleness index reflecting compressibility;
and determining macroscopic distribution of all main force small layers in the production area on the regional space according to reservoir data, crack number and mechanical data of the well points of the horizontal well, seismic data, mechanical data and fracturing prediction data among the wells.
Further, the reservoir dynamic recognition unit after fracturing modification is specifically used for:
inverting apparent parameters of the fractured reservoir according to the well test data, the production dynamic data and various production models of the production area;
determining the probability distribution range of single well productivity according to production dynamic data and the distribution rule of the productivity key characterization parameters in the effective reservoir parameters after fracturing;
and classifying the single wells with the determined productivity according to the gas well classification evaluation standards with benefits as guidance at different stages.
Further, the planar well distance evaluation unit is specifically configured to:
determining interference probability according to the relation between the microseism event and the effective stitch length;
determining a communication mode according to the interference well test result;
determining interference intensity according to production dynamic evaluation productivity index change;
based on the interference probability, the communication mode and the interference intensity, optimizing the multi-joint network parameters by taking the single-well productivity index as an objective function and the fracturing scale as a constraint condition, and obtaining the well spacing of the gas well under the condition of maximizing the single-well productivity index;
and (3) taking the multi-well dynamic accumulation yield as an optimization target, taking the total proppant volume as an internal constraint condition, taking the gas well development economy as an external constraint condition, and globally optimizing well spacing and network-sewing parameters.
The invention has the beneficial effects that: the shale gas can be comprehensively known, so that the shale gas key development technical policy is determined, and efficient development of the shale gas is realized.
Additional features and advantages of the invention will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by practice of the invention. The objectives and other advantages of the invention may be realized and attained by the structure particularly pointed out in the written description and claims hereof as well as the appended drawings.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings that are required in the embodiments or the description of the prior art will be briefly described, and it is obvious that the drawings in the following description are some embodiments of the present invention, and other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.
FIG. 1 shows a flow diagram of a shale gas development evaluation method according to an embodiment of the invention;
FIG. 2 shows a schematic diagram of a specific operation flow of a shale gas development evaluation method according to an embodiment of the invention;
FIG. 3 illustrates a schematic view of a cross-section of a slotted network perpendicular to a horizontal bore in accordance with an embodiment of the present invention;
FIG. 4 shows Chuannan Dragon one in an embodiment according to the invention 1 A stress sensitivity curve of the sub Duan Yeyan rock sample fracturing fluid after soaking;
FIG. 5 shows a schematic representation of a shale post-fracture gas well physical model concept in accordance with an embodiment of the present invention;
fig. 6 shows a schematic structural diagram of a shale gas development evaluation system according to an embodiment of the invention.
Detailed Description
For the purpose of making the objects, technical solutions and advantages of the embodiments of the present invention more apparent, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings in the embodiments of the present invention, and it is apparent that the described embodiments are some embodiments of the present invention, but not all embodiments of the present invention. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
Planar well spacing evaluation, longitudinal well pattern evaluation and production system evaluation are key to efficiently developing shale gas. The shale gas development evaluation method and the flow processing system provided by the embodiment of the invention can be used for characterizing the characteristics of shale reservoirs before and after fracturing, evaluating the production capacity of a shale gas well after fracturing and determining the reasonable development technical policy of shale gas.
Referring to fig. 1, fig. 1 shows a schematic flow chart of a shale gas development evaluation method according to an embodiment of the invention.
A shale gas development evaluation method comprises the following steps:
s1, acquiring static characteristics of the produced area before fracturing of the favorable reservoir according to favorable reservoir section identification, reservoir quality classification evaluation and reservoir spread evaluation.
S2, inverting the fracture network parameters after fracturing of the shale gas well based on static characteristics and production dynamic data before fracturing of the favorable reservoir in the production area, and carrying out gas well productivity evaluation and classification evaluation to obtain the characteristics of the reservoir after fracturing.
According to mass production dynamic data of a gas well in a production area, inverting effective artificial joint network characteristics after fracturing by means of various theoretical models; based on the inversion of the effective artificial joint network characteristics after fracturing, the gas well productivity evaluation and the gas well classification evaluation are carried out, and the distribution characteristics and the flow capacity of the reservoir after fracturing modification are comprehensively known from the dynamic aspect.
And S3, analyzing the reservoir connectivity after fracturing by utilizing qualitative and quantitative various technical methods, and determining the optimal development well spacing of the production area.
S4, evaluating the longitudinal well pattern deployment of the production area on the basis of the pattern sewing shape analysis.
S5, determining a reasonable development mode and real-time production allocation of the gas well based on quantitative characterization of stress sensitivity of shale reservoirs in the production area.
The shale gas development evaluation method provided by the embodiment of the invention can comprehensively recognize the shale gas, so that the shale gas key development technical policy is determined, and the efficient development of the shale gas is realized.
Referring to fig. 2, fig. 2 is a schematic diagram illustrating a specific operation flow of a shale gas development evaluation method according to an embodiment of the invention.
In specific implementation, the shale gas development evaluation method comprises the steps of comprehensively recognizing shale gas and efficiently developing the shale gas. The method is favorable for identifying the stratum section, classifying and evaluating the quality of the reservoir, and finely evaluating the spreading of the reservoir, wherein shale reservoir before fracturing modification is known from the static state; well testing or production dynamic evaluation, gas well productivity evaluation and gas well classification evaluation are shale reservoirs after fracturing modification are dynamically known. Planar well spacing evaluation, longitudinal well pattern evaluation and production system evaluation are key to efficiently developing shale gas. According to the shale gas development and evaluation technical method and process, the characteristics of shale reservoirs before and after fracturing can be recognized, the production capacity of a shale gas well after fracturing is evaluated, and the reasonable development technical policy of shale gas is determined.
Specifically, according to the identification of favorable stratum section, the quality classification evaluation of the reservoir and the distribution evaluation of the reservoir, the method for acquiring the static characteristics of the favorable reservoir in the production area before fracturing comprises the following steps:
s11, obtaining microscopic pore structure characterization and mineral composition of the production area according to the geochemical parameters, the geophysical parameters and the geological comprehensive parameters.
S12, determining shale localization evaluation indexes and classification standards of the favorable layer segments according to the microcosmic pore structure representation and the mineral composition.
S13, comprehensively determining reservoir classification of the production area according to index gas content of the reservoir macroscopically reflecting material foundation and index brittleness index reflecting compressibility.
S14, determining macroscopic distribution of each principal force small layer in the area space of the production area according to reservoir data, crack number and mechanical data of the well points of the horizontal well, seismic data, mechanical data and fracturing prediction data among the wells.
In specific implementation, acquiring static characteristics before fracturing comprises microscopic identification, macroscopic reservoir classification, three-dimensional space spreading and the like. Firstly, through shale reservoir microscopic pore structure characterization and organic matter-rich shale reservoir nano pore development rule research, simultaneously, the relation between pore development and reservoir mineral composition is finely described, main control factors of pore development and mineral composition are researched, and favorable reservoir section geochemistry evaluation indexes and classification standards are comprehensively established. Based on the method, the data such as well point core, well logging (including imaging special logging) and the like are utilized, shale reservoir macro-classification indexes are optimized, and shale reservoir macro-classification standards are established corresponding to development dynamic reactions of single wells. And predicting three-dimensional spatial distribution of the reservoir by using reservoir data, the number of cracks and mechanical data of a plurality of well points, particularly reservoir data, the number of cracks and mechanical data of a plurality of layer penetrating points of a horizontal well, integrating seismic data, microseism monitoring results and regional stress distribution among wells, and identifying an original reservoir before fracturing modification.
Based on static characteristics and production dynamic data before fracturing of the favorable reservoir in the production area, inverting the fracture network parameters after fracturing of the shale gas well, and carrying out gas well productivity evaluation and classification evaluation, wherein the step of acquiring the characteristics of the reservoir after fracturing comprises the following steps:
s21, inverting apparent parameters of the reservoir after fracturing according to well test data, production dynamic data and various production models of the production area.
It should be noted that the apparent parameter of the reservoir is the artificial stitch net parameter. The shale gas is developed by the artificial fracture network, the artificial fracture network after fracturing modification is influenced by factors such as original reservoir stress distribution, artificial modification technology, various parameters, pressure distribution in adjacent well sweep ranges and the like, influence factors are complex, main control factors are undefined, forward artificial fracture network distribution difficulty is high, and the effective artificial fracture network characteristics are inverted by a plurality of production theoretical models through easily-obtained mass production dynamic data.
In the specific implementation, because the scale difference of the manual stitch net is large, the scale characterization is carried out when the theoretical model is established. The main cracks near the shaft are characterized by adopting a discrete model, and the core parameters are crack morphological parameters; the secondary cracks in the SRV region are mainly controlled by stress distribution, are much and complex, but have certain regularity, are characterized by adopting a fractal model, have core parameters of fractal dimension of a secondary crack system, and can obtain experience values according to core or outcrop mechanics experiments; the micro-crack of the far-shaft area is small in size and free of propping agent support, the same continuous model representation as the matrix is adopted, the core parameter is the effective permeability of mixed flow with the matrix, and the core parameter can be obtained according to a core experiment.
S22, determining the probability distribution range of single well productivity according to production dynamic data and the distribution rule of the productivity key characterization parameters in the effective reservoir parameters after fracturing;
s23, classifying the single wells with the determined productivity according to the gas well classification evaluation standards with benefits as guidance at different stages.
In this step, the single wells with determined productivity are classified according to the size of the stitch net of the single well.
When the productivity evaluation of the gas well is implemented, the product of the half length of a fracture system and the effective permeability of a seepage area after fracturing to the power of 0.5 can be obtained by fitting through the production dynamic data of the early linear flow stage to be a determined valueHowever, since the effective permeability of the fractured seepage area and the half length of the fracture system are difficult to obtain accurately, the probability method is adopted to determine the distribution range of one parameter, for example, the effective permeability is taken as an example, the minimum effective permeability is taken as the matrix permeability, the maximum effective permeability is the permeability when the tomorrow reaches the boundary, and the probability distribution is generated after the range and the distribution form of the effective permeability are determined and simulated for multiple timesThe curve also corresponds to a probability distribution curve of the half length of the fracture system, namely a probability distribution curve and an accumulated probability distribution curve representing the EUR of a single well can be calculated, and P10, P50 and P90 on the accumulated probability distribution curve are respectively a conservation value, a median value and an optimistic value.
Specifically, the method for analyzing the connectivity of the reservoir after fracturing by utilizing qualitative and quantitative various technical methods and determining the optimal development well spacing of the production area comprises the following steps:
s31, determining interference probability according to the relation between the microseism event and the effective stitch length;
s32, determining a communication mode according to an interference well test result;
s33, determining interference intensity according to production dynamic evaluation productivity index change;
s34, optimizing multi-seam network parameters by taking a single-well productivity index as an objective function and a fracturing scale as a constraint condition based on the interference probability, the communication mode and the interference intensity, and obtaining a well distance under the condition of maximizing the single-well productivity index;
s35, taking the multi-well dynamic accumulation yield as an optimization target, taking the total volume of the propping agent as an internal constraint condition, taking the gas well development economy as an external constraint condition, and globally optimizing well spacing and network-sewing parameters.
It should be noted that the total proppant volume is related to the fracturing scale.
Specifically, on the basis of the analysis of the pattern of the patterns, the evaluation of the longitudinal well pattern deployment of the production area comprises the following steps:
s41, analyzing shale gas well network parameters through a finite element method to obtain shale gas well network morphology.
S42, obtaining the longitudinal high-quality small-layer reserve distribution of the gas well based on the hydraulic fracturing physical simulation experiment, the on-site tracer dynamic monitoring and the gas well production dynamic evaluation result of the target body position at the adjacent layers.
S43, establishing a star-shaped fracture network section mathematical model according to the fracture network shape of the shale gas well and the longitudinal high-quality small-layer reserves distribution of the gas well, wherein the star-shaped fracture network section mathematical model is specifically as follows:
wherein: y is the vertical distance of the volume element from m; b is the maximum vertical distance of the volume element from the shaft, m; x is the lateral extension length of the crack at a position y from the height of the shaft, m; a is the maximum extension length of the fracture lateral from the position y of the well bore height, m.
S44, evaluating longitudinal well pattern deployment of the production area according to the star-shaped seam network section mathematical model.
It should be noted that the development of longitudinal layer seams limits the extent of the seam network in height, and the seam network height decreases exponentially with distance away from the perforation point.
Referring to fig. 3, fig. 3 shows a schematic view of a cross section of a slotted screen perpendicular to a horizontal bore in accordance with an embodiment of the present invention.
The embodiment of the invention comprehensively provides the understanding of the cross section of the star-shaped slotted network vertical to the horizontal shaft based on the researches on the aspects of hydraulic fracturing physical simulation experiment, on-site tracer dynamic monitoring, gas well production dynamic evaluation result comparison of the target body position at the adjacent layer, shale gas well slotted network simulation by a finite element method and the like, and establishes a mathematical model of the cross section of the star-shaped slotted network. Based on the method, the longitudinal well pattern deployment is optimized, the staggered deployment can effectively reduce the network-sewing interference and improve the reserve utilization degree.
Specifically, based on the quantitative characterization of shale reservoir stress sensitivity in the production area, determining a reasonable development mode and real-time production allocation of a gas well comprises the following steps:
s51, determining that the shale reservoir stress sensitivity coefficient gamma is a gas well production pressure difference function of the soft stratum according to mechanism analysis and core experiments, and obtaining a shale permeability stress sensitivity curve.
In this step, the following relationship exists between the core permeability and the effective stress or the production pressure difference:
K(σ eff )=A exp[-γ(σ eff )]or (b)
Wherein: k is permeability, m 2 The method comprises the steps of carrying out a first treatment on the surface of the A is a coefficient; gamma is shale permeability stress sensitivity coefficient; sigma (sigma) eff To be effective stress, P a The method comprises the steps of carrying out a first treatment on the surface of the P is the formation pressure, P a ;p i Is the original formation pressure, pa; alpha is the Biot coefficient; v is the rock poisson ratio; Δp is the differential pressure produced, P a 。
In this step, the gas well production pressure difference function is specifically as follows:
wherein: gamma is the shale reservoir stress sensitivity coefficient; Δp is the production differential pressure; A. b, C is a constant.
Referring to FIGS. 4 and 5, FIG. 4 shows Chuannan-Longyan in an embodiment of the invention 1 Fig. 5 shows a schematic diagram of a physical model concept of a shale-fracturing gas well according to an embodiment of the invention, according to a stress sensitivity curve of a sub Duan Yeyan rock sample fracturing fluid after soaking.
S52, establishing a shale gas well physical model after shale fracturing according to the shale permeability stress sensitivity curve, taking a single-section main fracture as a unit, establishing a bilinear flow mathematical model of gas flowing into the fracture from the stratum and flowing into the shaft from the fracture, and obtaining a shale gas well instantaneous inflow dynamic curve by superposing the shale permeability stress sensitivity curve through yield.
In the step, the instantaneous inflow dynamic curve of the shale gas well is specifically as follows:
wherein: q (Q) g The production of the gas well is m/s; m is the pseudo pressure, P a 2 ;p i 、p wf Respectively the original stratum pressure and the bottom hole flow pressure, P a ;K m 、K f Matrix and fracture system permeability, m 2 ;t a Is the material equilibration time, s; gamma ray m 、γ mi Stress sensitivity coefficients of a certain moment and an original state are respectively obtained; w (w) f 、x f The width and half length of the main fracture zone, m; b is a volume coefficient; mu is the viscosity of the gas at the formation pressure at a certain moment, P a S; h is the effective reservoir thickness, m.
S53, based on the instantaneous inflow dynamic curve of the shale gas well in the production area, comprehensively optimizing the gas well production allocation by combining with economic evaluation, and determining a reasonable development mode and real-time production allocation of the gas well.
In specific implementation, according to the shale permeability stress sensitivity curve obtained through experiments, a shale gas well instantaneous inflow dynamic curve chart is calculated and drawn through theoretical calculation, and the gas well yield allocation is comprehensively optimized by combining economic evaluation, so that the cumulative yield and the extraction degree in an SRV zone are improved to the greatest extent.
It should be noted that, in the SRV region of the shale gas well, a large amount of gas is still stored in the matrix blocks, and needs to be extracted through the slotted network seepage channel, so that maintaining the effectiveness of the seepage channel is one of the core means for improving the recovery efficiency. The mechanism analysis shows that the characteristics of the shale gas lamellar reservoir structure and the soft stratum determine that the shale reservoir has strong stress sensitivity, and the stress sensitivity degree is changed along with the change of effective stress. Experiments show that the shale permeability stress sensitivity coefficient, which is a key parameter between shale core permeability and production pressure difference, is a function of the production pressure difference in a soft stratum and is not a fixed value, and the shale permeability stress sensitivity curve can be obtained through experiments. Based on the method, a physical and mathematical model is established, a shale gas well instantaneous inflow dynamic curve plate is calculated and drawn, and the gas well yield allocation is comprehensively optimized by combining economic evaluation, so that the cumulative yield and the extraction degree in the SRV region are improved to the greatest extent.
According to the shale gas development evaluation method, reservoirs before fracturing can be identified statically according to microscopic identification, macroscopic classification evaluation and spatial spreading. The reservoir after fracturing can be dynamically recognized through well testing or production dynamic theory inversion, probabilistic capacity evaluation of the gas well and classification evaluation of the gas well. And finally, key parameters for improving shale gas recovery efficiency and development benefits can be determined through key development technical policy optimization such as planar well spacing, longitudinal well patterns, gas well production system and the like.
Referring to fig. 6, fig. 6 shows a schematic structural diagram of a shale gas development evaluation system according to an embodiment of the invention.
The embodiment of the invention also provides a shale gas development evaluation system, which comprises:
and the reservoir static recognition unit before fracturing modification acquires static characteristics of the produced area before fracturing of the favorable reservoir according to favorable reservoir section identification, reservoir quality classification evaluation and reservoir spreading evaluation.
And the reservoir dynamic recognition unit after fracturing modification inverts the fracture network parameters after fracturing of the shale gas well based on static characteristics and production dynamic data before fracturing of the favorable reservoir in the production area, and carries out gas well productivity evaluation and classification evaluation to acquire the characteristics of the reservoir after fracturing.
And the planar well spacing evaluation unit is used for analyzing the connectivity of the reservoir after fracturing by utilizing a plurality of qualitative and quantitative technical methods and determining the optimal development well spacing of the production area.
And the longitudinal well pattern evaluation unit is used for evaluating the longitudinal well pattern deployment of the production area on the basis of the seam pattern shape analysis.
And the production system evaluation unit is used for determining a reasonable development mode and real-time production allocation of the gas well based on the quantitative characterization of the stress sensitivity of the shale reservoir in the production area.
Further, the reservoir static recognition unit before fracturing modification is specifically used for: obtaining microscopic pore structure characterization and mineral composition of the production area according to geochemical parameters, geophysical parameters and geological comprehensive parameters; determining shale localization evaluation indexes and classification standards of the favorable layer segments according to the microcosmic pore structure representation and the mineral composition; comprehensively determining reservoir classification of the production area according to index gas content of a reservoir macroscopic reflection substance foundation and index brittleness index reflecting compressibility; and determining macroscopic distribution of all main force small layers in the production area on the regional space according to reservoir data, crack number and mechanical data of the well points of the horizontal well, seismic data, mechanical data and fracturing prediction data among the wells.
Further, the reservoir dynamic recognition unit after fracturing modification is specifically used for: inverting apparent parameters of the fractured reservoir according to the well test data, the production dynamic data and various production models of the production area; determining the probability distribution range of single well productivity according to production dynamic data and the distribution rule of the productivity key characterization parameters in the effective reservoir parameters after fracturing; and classifying the single wells with the determined productivity according to the gas well classification evaluation standards with benefits as guidance at different stages.
Further, the planar well distance evaluation unit is specifically configured to: determining interference probability according to the relation between the microseism event and the effective stitch length; determining a communication mode according to the interference well test result; determining interference intensity according to production dynamic evaluation productivity index change; based on the interference probability, the communication mode and the interference intensity, optimizing the multi-joint network parameters by taking the single-well productivity index as an objective function and the fracturing scale as a constraint condition, and obtaining the well spacing of the gas well under the condition of maximizing the single-well productivity index; and (3) taking the multi-well dynamic accumulation yield as an optimization target, taking the total proppant volume as an internal constraint condition, taking the gas well development economy as an external constraint condition, and globally optimizing well spacing and network-sewing parameters.
Although the invention has been described in detail with reference to the foregoing embodiments, it will be understood by those of ordinary skill in the art that: the technical scheme described in the foregoing embodiments can be modified or some technical features thereof can be replaced by equivalents; such modifications and substitutions do not depart from the spirit and scope of the technical solutions of the embodiments of the present invention.
Claims (13)
1. The shale gas development evaluation method is characterized by comprising the following steps of:
acquiring static characteristics of the producing area before fracturing of the favorable reservoir according to the favorable reservoir section identification, the reservoir quality classification evaluation and the reservoir spread evaluation;
inverting the fracture network parameters after fracturing of the shale gas well based on static characteristics and production dynamic data before fracturing of the favorable reservoir in the production area, and carrying out gas well productivity evaluation and classification evaluation to obtain the characteristics of the reservoir after fracturing;
analyzing the connectivity of the reservoir after fracturing by using qualitative and quantitative various technical methods, and determining the optimal development well spacing of the production area;
on the basis of the seam network shape analysis, evaluating longitudinal well pattern deployment of the production area;
based on the quantitative characterization of shale reservoir stress sensitivity in the production area, a reasonable development mode and real-time production allocation of the gas well are determined.
2. The shale gas development evaluation method according to claim 1, wherein the step of obtaining static characteristics of the producing area before fracturing of the favorable reservoir comprises the following steps of:
obtaining microscopic pore structure characterization and mineral composition of the production area according to geochemical parameters, geophysical parameters and geological comprehensive parameters;
determining shale localization evaluation indexes and classification standards of the favorable layer segments according to the microcosmic pore structure representation and the mineral composition;
comprehensively determining reservoir classification of the production area according to index gas content of a reservoir macroscopic reflection substance foundation and index brittleness index reflecting compressibility;
and determining macroscopic distribution of all main force small layers in the production area on the regional space according to reservoir data, crack number and mechanical data of the well points of the horizontal well, seismic data, mechanical data and fracturing prediction data among the wells.
3. The shale gas development evaluation method according to claim 1, wherein the shale gas well fracturing after-fracture network parameters are inverted based on static characteristics and production dynamic data before fracturing of the favorable reservoir in the production area, the gas well productivity evaluation and classification evaluation are performed, and the reservoir characteristics after fracturing are obtained, and the steps of:
inverting apparent parameters of the fractured reservoir according to the well test data, the production dynamic data and various production models of the production area;
determining the probability distribution range of single well productivity according to production dynamic data and the distribution rule of the productivity key characterization parameters in the effective reservoir parameters after fracturing;
and classifying the single wells with the determined productivity according to the gas well classification evaluation standards with benefits as guidance at different stages.
4. A shale gas development evaluation method according to any of claims 1-3, wherein analyzing reservoir connectivity after fracturing using qualitative and quantitative multiple techniques, determining an optimal development well spacing for a production zone comprises the steps of:
determining interference probability according to the relation between the microseism event and the effective stitch length;
determining a communication mode according to the interference well test result;
determining interference intensity according to production dynamic evaluation productivity index change;
based on the interference probability, the communication mode and the interference intensity, optimizing the multi-joint network parameters by taking the single-well productivity index as an objective function and the fracturing scale as a constraint condition, and obtaining the well spacing of the gas well under the condition of maximizing the single-well productivity index;
and (3) taking the multi-well dynamic accumulation yield as an optimization target, taking the total proppant volume as an internal constraint condition, taking the gas well development economy as an external constraint condition, and globally optimizing well spacing and network-sewing parameters.
5. A shale gas development evaluation method according to any of claims 1-3, wherein evaluating the longitudinal well pattern deployment of the production zone based on the analysis of the fracture network morphology comprises the steps of:
analyzing shale gas well network parameters by a finite element method to obtain shale gas well network morphology;
based on a hydraulic fracturing physical simulation experiment, on-site tracer dynamic monitoring and gas well production dynamic evaluation results of the target body position at adjacent layers, obtaining longitudinal high-quality small-layer reserve distribution of the gas well;
establishing a star-shaped fracture network section mathematical model according to the fracture network shape of the shale gas well and the longitudinal high-quality small-layer reserves distribution of the gas well;
and evaluating the longitudinal well pattern deployment of the production area according to the star-shaped seam network section mathematical model.
6. The shale gas development evaluation method according to any one of claims 1-3, wherein determining a reasonable development mode and real-time production allocation of a gas well based on quantitative characterization of stress sensitivity of shale reservoirs in a production area comprises the following steps:
according to mechanism analysis and core experiments, determining that the shale reservoir stress sensitivity coefficient gamma is a gas well production pressure difference function of a soft stratum, and obtaining a shale permeability stress sensitivity curve;
according to the shale permeability stress sensitivity curve, a shale gas well physical model after fracturing is established, a single-section main fracture is taken as a unit, a bilinear flow mathematical model of gas flowing into the fracture from the stratum and flowing into the shaft from the fracture is established, and a shale gas well instantaneous inflow dynamic curve is obtained by superposing the shale permeability stress sensitivity curve through the yield;
based on the instantaneous inflow dynamic curve of the shale gas well in the production area, the gas well production allocation is comprehensively optimized by combining economic evaluation, and the reasonable development mode and real-time production allocation of the gas well are determined.
7. The shale gas development evaluation method according to claim 5, wherein the star-shaped slotted network section mathematical model is specifically as follows:
wherein: y is the vertical distance of the volume element from m; b is the maximum vertical distance of the volume element from the shaft, m; x is the lateral extension length of the crack at a position y from the height of the shaft, m; a is the maximum extension length of the fracture lateral from the position y of the well bore height, m.
9. The shale gas development evaluation method according to claim 6, wherein the shale gas well instantaneous inflow dynamic curve is specifically as follows:
wherein: q (Q) g The production of the gas well is m/s; m is the pseudo pressure, P a 2 ;p i 、p wf Respectively the original stratum pressure and the bottom hole flow pressure, P a ;K m 、K f Matrix and fracture system permeability, m 2 ;t a Is the material equilibration time, s; gamma ray m 、γ mi Stress sensitivity coefficients of a certain moment and an original state are respectively obtained; w (w) f 、x f The width and half length of the main fracture zone, m; b is a volume coefficient; mu is the viscosity of the gas at the formation pressure at a certain moment, P a S; h is the effective reservoir thickness, m.
10. A shale gas development evaluation system, comprising:
the reservoir static recognition unit before fracturing modification acquires static characteristics of the producing area before fracturing of the favorable reservoir according to favorable reservoir section identification, reservoir quality classification evaluation and reservoir spreading evaluation;
the reservoir dynamic recognizing unit after fracturing modification inverts the fracture network parameters after fracturing of the shale gas well based on static characteristics and production dynamic data before fracturing of the favorable reservoir in the production area, and carries out gas well productivity evaluation and classification evaluation to acquire the characteristics of the reservoir after fracturing;
the plane well spacing evaluation unit is used for analyzing the connectivity of the reservoir after fracturing by utilizing a plurality of qualitative and quantitative technical methods and determining the optimal development well spacing of the production area;
the longitudinal well pattern evaluation unit is used for evaluating the longitudinal well pattern deployment of the production area on the basis of the seam pattern shape analysis;
and the production system evaluation unit is used for determining a reasonable development mode and real-time production allocation of the gas well based on the quantitative characterization of the stress sensitivity of the shale reservoir in the production area.
11. The shale gas development evaluation system of claim 10, wherein the reservoir static awareness unit before fracturing modification is specifically configured to:
obtaining microscopic pore structure characterization and mineral composition of the production area according to geochemical parameters, geophysical parameters and geological comprehensive parameters;
determining shale localization evaluation indexes and classification standards of the favorable layer segments according to the microcosmic pore structure representation and the mineral composition;
comprehensively determining reservoir classification of the production area according to index gas content of a reservoir macroscopic reflection substance foundation and index brittleness index reflecting compressibility;
and determining macroscopic distribution of all main force small layers in the production area on the regional space according to reservoir data, crack number and mechanical data of the well points of the horizontal well, seismic data, mechanical data and fracturing prediction data among the wells.
12. The shale gas development evaluation system according to claim 10, wherein the reservoir dynamic recognition unit after fracturing modification is specifically configured to:
inverting apparent parameters of the fractured reservoir according to the well test data, the production dynamic data and various production models of the production area;
determining the probability distribution range of single well productivity according to production dynamic data and the distribution rule of the productivity key characterization parameters in the effective reservoir parameters after fracturing;
and classifying the single wells with the determined productivity according to the gas well classification evaluation standards with benefits as guidance at different stages.
13. The shale gas development evaluation system according to any of claims 10-12, wherein the planar interval evaluation unit is specifically configured to:
determining interference probability according to the relation between the microseism event and the effective stitch length;
determining a communication mode according to the interference well test result;
determining interference intensity according to production dynamic evaluation productivity index change;
based on the interference probability, the communication mode and the interference intensity, optimizing the multi-joint network parameters by taking the single-well productivity index as an objective function and the fracturing scale as a constraint condition, and obtaining the well spacing of the gas well under the condition of maximizing the single-well productivity index;
and (3) taking the multi-well dynamic accumulation yield as an optimization target, taking the total proppant volume as an internal constraint condition, taking the gas well development economy as an external constraint condition, and globally optimizing well spacing and network-sewing parameters.
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CN116307871A (en) * | 2023-03-06 | 2023-06-23 | 中国地质调查局油气资源调查中心 | Method for evaluating shale microcosmic reservoir space effectiveness |
CN116894572A (en) * | 2023-09-11 | 2023-10-17 | 西南石油大学 | Reasonable production allocation method for ultra-deep well considering sand production after rock collapse |
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CN116307871A (en) * | 2023-03-06 | 2023-06-23 | 中国地质调查局油气资源调查中心 | Method for evaluating shale microcosmic reservoir space effectiveness |
CN116307871B (en) * | 2023-03-06 | 2023-10-27 | 中国地质调查局油气资源调查中心 | Method for evaluating shale microcosmic reservoir space effectiveness |
CN116894572A (en) * | 2023-09-11 | 2023-10-17 | 西南石油大学 | Reasonable production allocation method for ultra-deep well considering sand production after rock collapse |
CN116894572B (en) * | 2023-09-11 | 2023-12-15 | 西南石油大学 | Reasonable production allocation method for ultra-deep well considering sand production after rock collapse |
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