CN111608649B - Method for predicting beneficial area of exogenous supply type shale gas exploration - Google Patents
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Abstract
The invention discloses a method for predicting a natural shale gas flow in a low-exploration-degree area, which can be used for identifying and predicting regional natural cracks in organic-rich shale, acquiring a permeability stress sensitivity function of cracks in the shale by fitting to reduce errors, introducing a virtual well single-well energy production prediction technology into favorable area evaluation to reduce investment risk, identifying the structure of a natural regional slip fault in the shale, quantitatively calculating the displacement of the slip fault and predicting fracture zone space distribution characteristics, avoiding the industrial bottleneck of artificial fracturing development of the existing shale gas, acquiring the permeability sensitivity function of cracks in the shale by fitting, realizing quantitative prediction of a permeability space change rule, and making up the technical defect that the single-well energy production prediction error is large by adopting a single fixed permeability value in the prior art.
Description
Technical Field
The invention discloses a method for predicting an advantageous zone of exogenous supply type shale gas exploration, relates to a method for predicting an advantageous zone of exogenous supply type shale gas exploration, and belongs to the field of natural gas identification. Particularly relates to a shale gas exploration favorable area prediction method which can predict natural shale gas flow in a low exploration degree area, recognize and predict regional natural fractures in organic-rich shale, obtain a fracture permeability stress sensitivity function in the shale through fitting to reduce errors, introduce a virtual well single well energy production prediction technology into favorable area evaluation and reduce investment risks.
Background
Shale gas is natural gas produced from fine particle sedimentary rocks such as organic-rich shale, the occurrence state of the shale gas is mainly free and adsorption states, compared with a conventional gas reservoir, the shale gas has the characteristics of delicate sealing mechanism, various overburden lithology and relatively short hydrocarbon migration distance, because the organic-rich shale is a very low-permeability compact stratum, the existing shale gas development is usually realized by means of artificial hydraulic fracturing, but with the rapid development of the shale gas industry, the shale gas development and fracturing cost is high, the environmental pollution is serious, earthquakes can be induced, deep shale gas resources of 4000m cannot be fully developed and utilized, the technical bottlenecks of the industry are increasingly prominent, and although the existing process attempts to reduce the fracturing cost from improving the fracturing fluid flowback rate and improve the fracturing capability and increase the fracturing capability, the technical bottlenecks of the industry can be relieved by burying the deep shale gas resources, the existing process cannot be fully broken through. He Jianglin, wang Jian, mu Xie, liu Wei, ku Xiang Ying, qihe courage and Qizheng in the text of discovery of exogenous supply type shale gas and geological significance of oil and gas (Petroleum institute, 2018,1 (39): 1-11.), on the basis of summarizing shale gas enrichment law of typical shale gas reservoir in China and massive section and core data, shale gas is divided into: the important discovery of obtaining shale gas is that in-situ enrichment type shale gas and exogenous replenishment type shale gas guide 1-well drilling of a Huadi to obtain natural shale gas flow according to an exogenous replenishment type shale gas enrichment mode, wherein the exogenous replenishment type shale gas refers to natural gas which is remained after hydrocarbon discharge and is supplied laterally by a fault or supplied vertically by micro leakage of an underlying gas reservoir in the organic-rich shale. Although the method has the functions of discharging hydrocarbons and dissipating natural gas, the supply rate of the natural gas is greater than the dissipation rate, dynamic enrichment is formed, the enrichment of shale gas in the dynamic enrichment is mainly controlled by fluid potential, exogenous supply type shale gas possibly has natural capacity due to the overpressure of the oil gas transportation layer with high permeability, and the shale gas is not paid high attention in the industry, so that at present, the prediction method for the shale gas exploration beneficial area is not available.
Disclosure of Invention
In order to improve the situation, the method for predicting the beneficial zone of the exogenous replenishment-type shale gas exploration, provided by the invention, can predict the natural shale gas flow in the zone with low exploration degree, identify and predict regional natural cracks in the shale with organic substances, obtain a crack permeability stress sensitivity function in the shale by fitting so as to reduce errors, and introduce a virtual well single-well energy production prediction technology into the beneficial zone for evaluation so as to reduce the investment risk.
The invention discloses a method for predicting an advantageous area of exogenous supply type shale gas exploration, which comprises the following steps:
1) Estimating the shale gas static resource amount in the research area;
2) Whether a typical lithologic combination which is easy to form a slipping fault is developed in a shale gas target layer or not and the distribution range of the lithologic combination are found out;
3) Finding out the structural style and geometric form of a target layer in a research area;
4) Quantitatively predicting the displacement of the upper plate and the lower plate of the slippage fault;
5) Performing typical lithology combined mechanical test;
6) Summarizing a crack space distribution rule in a research area;
7) Carrying out seepage experiment tests under different confining pressure and pore pressure conditions, and establishing a crack permeability stress sensitivity function;
8) Carrying out shale gas desorption rule test research;
9) Analyzing the influence radius of the single virtual well;
10 Virtual well mobility shale gas resource quantity estimation;
11 Obtaining seepage key parameter values of different structural parts by combining with fluid potential analysis of a research area;
12 Estimate the virtual well site single well productivity;
13 Delineating the beneficial zone range of the exogenous supply type shale gas;
further, the step 1 of estimating the static resource amount of the shale gas in the research area is completed by adopting a volume method;
further, the typical lithology combination for finding out whether the shale gas target layer is developed to form the slippage fault or not in the step 2 is found out by adopting field investigation, core observation and lithology explanation of well logging;
further, the distribution range of the lithological combination is found out in the step 2 by combining sedimentary facies, existing regional structures or seismic data, the distribution range of the lithological combination is preliminarily found out, and the distribution rule of the fractured zones is summarized in the field outcrop and the rock core according to the typical characteristics of the fractured zones of the slippage under different scales;
further, the step 3 finds out the tectonic pattern and the geometric form of the target layer in the research area, and the tectonic pattern and the geometric form of the geovoltaic structure of the research area are clear through tectonic geological survey and two-dimensional seismic profile tectonic interpretation;
further, step 4, acquiring stratum thickness, dip angle and curved surface functions related to the slip displacement calculation according to the geometrical form and lithology combination characteristics of the earth-potential structure, selecting a corresponding slip displacement quantitative calculation formula for different structure pattern parts, and acquiring a semi-quantitative prediction result of the slip displacement;
further, the step 5 is to perform a typical lithology combination mechanical test to obtain mechanical parameters required by crack prediction;
furthermore, in the step 6, a discrete element numerical simulation method is adopted to predict the spatial distribution rule of the cracks in the research area, and the method of outcrop observation, micron CT and scanning electron microscope is combined to correct the summary and prediction result of the spatial distribution rule of the cracks;
further, the step 7 is to perform seepage experiment tests under different confining pressures and pore pressure conditions, obtain fracture permeability values under different pore pressures and confining pressures through tests, and obtain a function relation of the fracture permeability along with changes of the pore pressure and the confining pressure through binary nonlinear fitting;
further, the shale gas desorption rule test research is carried out in the step 8, the formation temperature and pressure condition is artificially simulated, after the sample is saturated and adsorbs methane, the gradual depressurization desorption process is simulated, and the shale gas desorption rule of the shale of the adjacent layer is obtained;
further, the virtual well single-well influence radius analysis of the step 9 adopts analysis structure geometric form and crack prediction analysis, identifies the trapping condition of the research area, and determines the single-well influence radius;
further, the single-well movable shale gas resource amount in the step 10 is completed by adopting a volume method on the basis of the influence radius and desorption rule of the single well;
further, the step 11 is combined with the fluid potential analysis of the research area to obtain key seepage parameter values of different structural parts, and the spatial variation rule of the permeability is obtained by inputting the pore pressure and confining pressure parameter values into the function relationship between the crack permeability and the pore pressure and confining pressure;
further, the step 12 of estimating the single-well productivity of the virtual well location is carried out by inputting the permeability, the thickness of a fracture zone, the bottom hole pressure, the formation boundary pressure, the temperature of a producing zone, the gas viscosity and the gas average deviation coefficient value of the virtual well into a conventional natural gas well productivity calculation empirical formula in a working area to obtain the single-well productivity of the virtual well location;
further, the step 13 of delineating the beneficial zone range of the exogenous supply type shale gas is performed after drilling verification or prediction parameter values are corrected through a prospect well.
Advantageous effects
1. The method can be used for carrying out structure recognition of natural regional slippage faults in the shale, quantitative calculation of slippage fault displacement and prediction of fracture zone space distribution characteristics, and avoids the industrial bottleneck that the existing shale gas needs manual fracturing development.
2. The permeability sensitivity function of the cracks in the shale is obtained through fitting, quantitative prediction of the spatial change rule of the permeability is achieved, and the technical defect that the single well productivity prediction error is large due to the adoption of a single fixed permeability value in the prior art is overcome.
3. The virtual well single-well energy production prediction technology is introduced into the favorable area evaluation, the well position optimization of the pre-exploration well and the commercial development value evaluation of the favorable area are facilitated, and the investment risk of the low-exploration-degree area can be greatly reduced.
Drawings
FIG. 1 is a flow chart of an implementation of the method for predicting an advantageous zone of exploration of exogenous replenishment-type shale gas according to the invention;
FIG. 2 is a geological meaning schematic diagram of a slippage fault displacement quantitative prediction function of different fold type structures in step 4 of the exogenous replenishment type shale gas exploration favorable area prediction method;
FIG. 3 is a diagram illustrating a functional relationship between permeability of a shale internal fracture in a certain area and changes of pore pressure and confining pressure according to binary nonlinear fitting based on measured data according to an embodiment of the present invention;
FIG. 4 is a schematic diagram of a virtual single well productivity prediction parameter in accordance with an embodiment of the present invention;
FIG. 5 is an identification feature of a natural fracture zone in organic-rich shale at different geological scales;
the specific implementation mode is as follows:
the invention discloses a method for predicting an advantageous area of exogenous supply type shale gas exploration, which comprises the following steps:
1) Estimating the shale gas static resource quantity in the research area: completing estimation of the static resource quantity of the shale gas of the target layer in the research area according to a volume method;
further, on the basis of regional geological survey or existing drilling data, calculating and evaluating technical specifications by referring to the current industry specification DZT0254-2014 shale gas resource reserves;
2) And (3) finding out whether the shale gas target layer develops typical lithologic combinations which are easy to form slip faults and the distribution range of the lithologic combinations: whether a target layer of the shale rich in organic matters has a typical lithology combination which is easy to develop and form a slipping fault or not is found through field investigation, core observation and lithology interpretation of well logging, namely whether the target layer has lithology combination characteristics of two thick layers of energy dry layers and a thin layer of soft and weak layers, the distribution range of the lithology combination is preliminarily found by combining sedimentary facies, existing regional structures or seismic data, and the distribution rule of the slipping fault crack zone is summarized in a field outcrop and a core according to the typical characteristics of the slipping fault crack zone under different scales;
3) Finding the structural style and geometric form of the target layer in the research area: through structural geological survey and two-dimensional seismic section structural explanation, the geologic structure style and the structural geometric form of a research area are defined;
4) Quantitative prediction of upper and lower disk displacement of a slippage fault: acquiring stratum thickness, dip angle and curved surface functions related to the slip displacement calculation according to the geometrical form and lithology combination characteristics of the earth-potential structure, and acquiring a semi-quantitative prediction result of the slip displacement;
further, selecting a corresponding slip displacement quantitative calculation formula (shown in figure 2) for different structural style parts;
5) Typical lithology combination mechanical tests were performed: performing mechanical test on each lithologic unit in the typical lithologic combination to obtain mechanical parameters of compression resistance, tensile strength, shear strength and Young modulus of the sample;
6) And (3) summarizing the spatial distribution rule of the cracks in the research area: on the basis of typical lithology unit mechanical test, a discrete element numerical simulation method is used for predicting the three-dimensional space distribution rule of the crack,
furthermore, a method for correcting the conclusion of the crack space distribution rule and the prediction result can adopt the methods of section observation, micron CT and scanning electron microscope;
furthermore, in step 6, a discrete element numerical simulation method is used to combine the geometric configuration of the structure of the research area, the ground stress and the structural action period secondary background data;
7) Carrying out seepage experiment tests under different confining pressure and pore pressure conditions, and establishing a crack seepage stress sensitivity function: testing and obtaining fracture permeability values under different pore pressures and confining pressures, and obtaining a function relation of the fracture permeability along with changes of the pore pressures and the confining pressures through binary nonlinear fitting;
in step 7, selecting a representative fracture sample, and applying different pore pressure differences along the direction of an oil and gas migration main body in the representative fracture sample under different confining pressure simulation states;
8) Carrying out shale gas desorption rule test research: selecting a shale sample rich in organic substances in a non-developing section of a crack of an adjacent layer of a regional crack zone, adopting a manual simulation formation temperature and pressure condition, and after the sample is saturated and adsorbs methane, simulating gradual depressurization and desorption to obtain a shale gas desorption rule of the adjacent layer of shale;
9) Analyzing the influence radius of each virtual well: identifying the trapping condition of the research area according to the construction geometry of the step 3 and the crack prediction analysis of the step 6, and determining the hydrocarbon supply radius of the virtual well position of the typical construction part, namely the single well influence radius;
10 Virtual well mobility shale gas resource quantity estimation: calculating and evaluating technical specifications and shale gas desorption rules in the step 8 according to the virtual well single well influence radius obtained in the step 9 and by referring to DZT0254-2014 shale gas resource reserves, and estimating the single well movable shale gas resource quantity;
11 Obtaining key seepage parameter values of different structural parts by combining with fluid potential analysis of a research area: inputting the predicted value into the function relation between the crack permeability, the pore pressure and the confining pressure obtained in the step 7, and obtaining the spatial change rule of the crack permeability in the research area;
further, on the basis of regional hydrology, drilling and logging information or stratum pressure prediction, a fluid potential distribution rule of a research area is determined, and pore pressure and confining pressure change rules and predicted values of different structural parts in the area are obtained according to the fluid potential distribution rule;
12 Estimate virtual well site single well productivity: inputting the permeability, the thickness of a fracture zone, the bottom pressure, the formation boundary pressure, the temperature of a producing zone, the gas viscosity and the average deviation coefficient value of the gas of the virtual well into a conventional natural gas well productivity calculation empirical formula in a work area to obtain the single-well productivity of the virtual well, such as a single-well productivity calculation formula in a certain area:
q sc is the flow at the surface of the gas well, m 3 D; t-producing formation temperature, K; k-formation permeability, 10 -3 μ m); μ -gas viscosity, mPa · s; p wf -bottom hole pressure, MPa; p e -formation boundary pressure, MPa; h-effective thickness of stratum (m), r e -radius of drainage (m), r w -wellbore radius (m), Z-formation gas mean deviation factor, empirical value of 0.94 in a certain area;
13 Define the range of the beneficial zone of the exogenous supply type shale gas:
and (4) after the drilling verification or the prediction parameter value is corrected through a pre-exploration well, defining the range of the beneficial area of the exogenous supply type shale gas. According to the step 8, considering the influence of the transition from the adsorption state to the free state in the shale gas exploitation process to slow down the formation pressure decay rate, and roughly evaluating the development value of the favorable area;
furthermore, on the basis of the production capacity prediction of virtual wells at different structural positions of the research area, the well position of the pre-exploration well is preferably predicted.
In the attached figure 5, a shows that the thickness of the slip fault fracture zone is stable in outcrop, the top and bottom surfaces of the slip fault fracture zone are in abrupt contact with surrounding rock, the layer surface of the undisturbed surrounding rock is flat, and the S-C cleavage characteristic formed by the shear stress in the fracture zone is obvious; b represents that the fracture zone of the part with small displacement is mainly fault cobbles and the cracks develop; c represents local multi-stage different stress direction action areas to develop a plurality of crack layers; d represents the rule that the size of fault cobbles is gradually reduced from surrounding rocks to a broken zone when the sliding layer in the rock core is found; e represents the erosion holes and crack development in the crack zone in the micrometer CT three-dimensional image; f represents a multi-stage calcite vein formed by visible shearing action in a part of crack zones in the sheet, and the activity time can be determined by measuring the age of the opposite litholytic vein; g represents the arrangement of calcite anser lines with accompanying cracks, and indicates the acting direction of the relative shear stress;
the method can predict the natural shale airflow in a low-exploration-degree area, identify and predict regional natural fractures in the organic-rich shale, obtain a fracture permeability stress sensitivity function in the shale through fitting to reduce errors, and introduce a virtual well single-well energy production prediction technology into favorable area evaluation to reduce investment risk.
It should be understood that the steps of the method for predicting the beneficial zone of the exogenous supply type shale gas exploration have specific compositions and structures, and those skilled in the art who reproduce the method need to have specific compositions in the steps, so that the technical characteristics of the method are functionally supported by each other, and a new technical effect is achieved.
In addition, the single well productivity calculation formula is derived from a conventional gas well single well productivity calculation formula, and part of parameters of the single well productivity calculation formula are experience values, so that the single well productivity calculation formula and the parameter values have certain differences due to geological conditions and well type differences. It will be understood by those skilled in the art that various modifications may be made without departing from the scope of the invention, and all such modifications are intended to be included within the scope of the present invention.
Claims (5)
1. The method for predicting the beneficial zone of the exogenous supply type shale gas exploration is characterized by comprising the following steps of:
1) Estimating the amount of shale gas static resources in the research area;
2) Whether a typical lithologic combination which is easy to form a slipping fault is developed in a shale gas target layer or not and the distribution range of the lithologic combination are found out;
3) Finding out the structural style and the geometric form of a target layer in a research area, and determining the tectonic style and the geometric form of the geologic horizon in the research area through structural geological survey and two-dimensional seismic profile structural explanation;
4) Quantitatively predicting the displacement of an upper plate and a lower plate of the slippage fault, acquiring stratum thickness, dip angle and curved surface functions related to the calculation of the slippage displacement according to the geometrical form and lithology combination characteristics of the geostationary structure, selecting a corresponding slippage displacement quantitative calculation formula for different structural style parts, and acquiring a semi-quantitative prediction result of the slippage displacement;
5) Performing typical lithology combined mechanical test to obtain mechanical parameters required by crack prediction;
6) Summarizing a spatial distribution rule of cracks in a research area, predicting the spatial distribution rule of the cracks in the research area by adopting a discrete element numerical simulation method, correcting the summarization and prediction results of the spatial distribution rule of the cracks by combining outcrop observation, micron CT and scanning electron microscope methods, and combining the structural geometric form, the ground stress and the structural action period secondary background data of the research area by using the discrete element numerical simulation method;
7) Carrying out seepage experiment tests under different confining pressures and pore pressure conditions, establishing a crack permeability stress sensitivity function, obtaining crack permeability values under different pore pressures and confining pressure states through the tests, and obtaining a function relation of the crack permeability along with the change of the pore pressures and the confining pressures through binary nonlinear fitting;
8) Carrying out shale gas desorption rule test research, adopting artificial simulation of formation temperature and pressure conditions, and simulating a gradual depressurization desorption process after the sample is saturated and adsorbs methane to obtain the shale gas desorption rule of the adjacent layer of shale;
9) Analyzing the single-well influence radius of the virtual well, identifying the trapping condition of the research area according to the structural geometric form in the step 3) and the crack prediction analysis in the step 6), and determining the single-well influence radius;
10 Estimating the movable shale gas resource amount of the virtual well, wherein the movable shale gas resource amount of a single well is completed by adopting a volume method on the basis of the single well influence radius in the step 9) and the shale gas desorption rule in the step 8);
11 Obtaining key seepage parameter values of different structural parts by combining with fluid potential analysis of a research area, inputting a predicted value into the function relation between the crack permeability and the pore pressure and confining pressure obtained in the step 7), and obtaining a spatial change rule of the crack permeability in the research area;
12 Estimating the single-well productivity of the virtual well position, and obtaining the single-well productivity by inputting the permeability, the thickness of a fracture zone, the bottom hole pressure, the formation boundary pressure, the temperature of a production layer, the gas viscosity and the gas average deviation coefficient value of the virtual well into a conventional natural gas well productivity calculation empirical formula in a work area;
13 On the basis of the prediction of the production capacity of virtual wells at different structural parts of a research area, the well position of a pre-exploration well is optimized, and after drilling verification or prediction parameter values are corrected through the pre-exploration well, the beneficial area range of the exogenous supply type shale gas is defined.
2. The method for predicting the advantageous zone of exogenous replenishment type shale gas exploration according to claim 1, wherein the step 12) of estimating the single well productivity of the virtual well site is obtained by inputting the permeability, the fracture zone thickness, the bottom hole pressure, the formation boundary pressure, the formation temperature, the gas viscosity and the gas mean deviation coefficient value of the virtual well into a conventional natural gas well productivity calculation empirical formula in the work area, wherein the single well productivity calculation formula is as follows:
q sc flow at the surface of the gas well, m 3 /d；T-producing formation temperature, K; k-formation permeability, 10 -3 Mu m; μ -gas viscosity, mPa · s;P wf -bottom hole pressure, MPa;P e -formation boundary pressure, MPa;h-the effective thickness m of the formation,r e -the radius m of the drainage oil is,r w -wellbore radius m, Z average deviation coefficient of formation gas.
3. The method for predicting the advantageous zone of exploration for the exogenous supply type shale gas as claimed in claim 1, wherein the distribution range of the lithologic combination is found in the step 2) by combining sedimentary facies, existing regional structures or seismic data to preliminarily find the distribution range of the lithologic combination, and the distribution rule of the fractured zones is summarized according to typical characteristics of fractured zones slipped under different scales in field outcrop and rock cores.
4. The method for predicting the beneficial zone of exploration of the exogenous supply type shale gas as claimed in claim 1, wherein in the step 11), on the basis of regional hydrology, well drilling and logging data or stratum pressure prediction, a fluid potential distribution rule of the research zone is determined, pore pressures and confining pressure change rules of different structural parts in the zone are obtained according to the fluid potential distribution rule, and the predicted value is input into the function relation between the fracture permeability and the pore pressures and the confining pressure obtained in the step 7), so that a space change rule of the fracture permeability in the research zone is obtained.
5. The method for predicting the beneficial zone of the exogenous supply type shale gas exploration according to claim 1, wherein the step 13) further comprises the step of roughly evaluating the development value of the beneficial zone according to the step 8) by considering the influence of the reduction of the formation pressure decay rate caused by the transition from the adsorption state to the free state in the shale gas exploitation process.
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| US8751208B2 (en) * | 2007-12-20 | 2014-06-10 | Shell Oil Company | Method for producing hydrocarbons through a well or well cluster of which the trajectory is optimized by a trajectory optimisation algorithm |
| CN103498670B (en) * | 2013-09-13 | 2016-04-06 | 中国石油天然气股份有限公司 | Horizontal well geological predication method and apparatus |
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