CN104453876B - Method and device for predicting oil and gas yield of horizontal well of compact oil and gas reservoir - Google Patents
Method and device for predicting oil and gas yield of horizontal well of compact oil and gas reservoir Download PDFInfo
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Abstract
The invention provides a method and a device for predicting oil and gas yield of a horizontal well of a compact oil and gas reservoir, wherein the method comprises the following steps: establishing a reservoir structure index model and a capacity heterogeneous index model of the drilled vertical well according to the drilling data of the drilled vertical well; establishing a maximum monthly yield prediction model of the drilled vertical well by utilizing the reservoir structure index model and the productivity heterogeneous index model; establishing a maximum monthly yield prediction model of the horizontal well to be drilled at the position corresponding to the model according to the maximum monthly yield prediction model of the drilled vertical well; and establishing a yield prediction model of the horizontal well to be drilled along with the production time according to the maximum monthly yield prediction model of the horizontal well to be drilled so as to predict the oil and gas yield of the horizontal well to be drilled along with the production time. The method can obtain the predicted yield which is more consistent with the oil and gas yield of the actual compact oil and gas reservoir horizontal well.
Description
Technical Field
The invention relates to the technical field of exploration and development of compact oil and gas reservoirs, in particular to a method and a device for predicting oil and gas yield of a horizontal well of a compact oil and gas reservoir.
Background
With the rapid development of oil and gas exploration and development from conventional oil and gas reservoirs to unconventional oil and gas (namely, dense oil and gas), dense oil and gas gradually becomes an important field of oil and gas exploration and development. In the process of compact oil and gas exploration and development, a core area is selected through evaluation, after a target interval is determined through drilling a vertical well and evaluation in the core area, a compact oil and gas reservoir is produced in the target interval in a horizontal well and volume fracturing mode. But not all horizontal wells in the core area can obtain economic oil and gas yield after volume fracturing; for example, in the U.S. where the exploration and development of compact hydrocarbons are most successful, 40% -50% of the produced compact hydrocarbon horizontal wells have no economic benefit. Generally, the oil and gas yield and the exploitation time of a compact oil and gas horizontal well are L-shaped, namely the initial-stage yield of the horizontal well is the largest, the oil and gas yield gradually decreases along with the extension of the exploitation time, the accumulated oil and gas yield of the production well can be predicted according to the oil and gas yield decreasing rule as long as the initial-stage maximum oil and gas yield of the horizontal well is determined, and the key for evaluating whether the single-well maximum oil and gas yield of the horizontal well can be obtained or not is how to accurately predict the single-well maximum oil and gas yield.
Different from the oil gas flow in the conventional oil gas reservoir conforming to the seepage principle, the overburden pressure matrix permeability of the compact reservoir is very low (generally less than 0.1mD), certain starting pressure exists, and after large-scale volume fracturing, oil gas in the compact reservoir has various flow modes such as seepage, diffusion and the like, namely, a fluid flow mechanism in the compact reservoir does not completely conform to the seepage theory, so that the oil gas yield prediction model obtained based on the seepage theory is still not suitable for predicting the yield of the compact oil gas reservoir in the prior art, the change relation of the yield of an oil gas well along with time is difficult to accurately reflect, and the error is large.
Disclosure of Invention
The invention aims to provide a method and a device for predicting oil and gas yield of a horizontal well of a compact oil and gas reservoir.
In order to achieve the above purpose, in one aspect, the embodiment of the invention provides a method for predicting oil and gas production of a horizontal well of a compact oil and gas reservoir, which comprises the following steps:
establishing a reservoir structure index model and a capacity heterogeneous index model of the drilled vertical well according to the drilling data of the drilled vertical well;
establishing a maximum monthly yield prediction model of the drilled vertical well by utilizing the reservoir structure index model and the productivity heterogeneous index model;
establishing a maximum monthly yield prediction model of the horizontal well to be drilled at the position corresponding to the model according to the maximum monthly yield prediction model of the drilled vertical well;
and establishing a yield prediction model of the horizontal well to be drilled along with the production time according to the maximum monthly yield prediction model of the horizontal well to be drilled so as to predict the oil and gas yield of the horizontal well to be drilled along with the production time.
Preferably, the reservoir structure index model is: rS＝γS(GR)×VSh；
Wherein R isSIs a reservoir structural index; gamma rayS(GR) is the natural gamma variance root function; GR is a natural gamma logging value; vShIs the mud content;
the productivity heterogeneous index model comprises the following steps:
in the formula, QHIs the heterogeneous index of productivity; gamma rayS(DEN) is the root function of variance of the density log; hiThe thickness of the oil layer of the ith layer;porosity of the ith layer; soiIs the oil saturation of the ith layer; giIs the pressure gradient of the ith layer; mu.siIs the crude oil viscosity of the i-th layer.
Preferably, the model for predicting the maximum monthly production of the drilled vertical well is as follows: qVmax＝a×QH/RS+b；
In the formula, QVmaxThe maximum monthly oil production of the drilled vertical well; rSIs a reservoir structural index; qHTo produce powerA heterogeneous index; a is a preset coefficient; b is a preset constant.
Preferably, the model for predicting the maximum monthly yield of the horizontal well to be drilled is as follows: qHmax＝c×QVmax d；
In the formula, QHmaxThe maximum monthly oil production of the horizontal well to be drilled; qVmaxThe maximum monthly oil production of the drilled vertical well; c is a preset coefficient; d is a preset exponential constant.
Preferably, the step of establishing a yield prediction model of the horizontal well to be drilled along with the change of production time according to the maximum monthly yield prediction model of the horizontal well to be drilled comprises the following steps:
establishing a prediction model of the horizontal well to be drilled, which changes in a descending rule along with the production time, according to the maximum monthly yield prediction model of the horizontal well to be drilled: qHmonth＝QHmax×tf；
In the formula, QHmaxThe maximum monthly oil production of the horizontal well to be drilled; t is the production time in months; qHmonthThe oil yield per month of the horizontal well to be drilled in the tth production time; f is a preset exponential constant, and the value of f is a negative value.
On the other hand, the embodiment of the invention also provides a device for predicting the oil and gas yield of the horizontal well of the compact oil and gas reservoir, which comprises the following steps:
the parameter model establishing module is used for establishing a reservoir structure index model and a capacity heterogeneous index model of the drilled vertical well according to the drilling data of the drilled vertical well;
the first yield model building module is used for building a maximum monthly yield prediction model of the drilled vertical well by utilizing the reservoir structure index model and the productivity heterogeneous index model;
the second yield model establishing module is used for establishing a maximum monthly yield prediction model of the horizontal well to be drilled at the position corresponding to the maximum monthly yield prediction model of the drilled vertical well according to the maximum monthly yield prediction model of the drilled vertical well;
and the oil and gas yield prediction module is used for establishing a yield prediction model of the horizontal well to be drilled along with the change of the production time according to the maximum monthly yield prediction model of the horizontal well to be drilled so as to predict the oil and gas yield of the horizontal well to be drilled along with the change of the production time.
Preferably, the reservoir structure index model is: rS＝γS(GR)×VSh；
Wherein R isSIs a reservoir structural index; gamma rayS(GR) is the natural gamma variance root function; GR is a natural gamma logging value; vShIs the mud content;
the productivity heterogeneous index model comprises the following steps:
in the formula, QHIs the heterogeneous index of productivity; gamma rayS(DEN) is the root function of variance of the density log; hiThe thickness of the oil layer of the ith layer;porosity of the ith layer; soiIs the oil saturation of the ith layer; giIs the pressure gradient of the ith layer; mu.siIs the crude oil viscosity of the i-th layer.
Preferably, the model for predicting the maximum monthly production of the drilled vertical well is as follows: qVmax＝a×QH/RS+b；
In the formula, QVmaxThe maximum monthly oil production of the drilled vertical well; rSIs a reservoir structural index; qHIs the heterogeneous index of productivity; a is a preset coefficient; b is a preset constant.
Preferably, the model for predicting the maximum monthly yield of the horizontal well to be drilled is as follows: qHmax＝c×QVmax d；
In the formula，QHmaxThe maximum monthly oil production of the horizontal well to be drilled; qVmaxThe maximum monthly oil production of the drilled vertical well; c is a preset coefficient; d is a preset exponential constant.
Preferably, the step of establishing a yield prediction model of the horizontal well to be drilled along with the change of production time according to the maximum monthly yield prediction model of the horizontal well to be drilled comprises the following steps:
establishing a prediction model of the horizontal well to be drilled, which changes in a descending rule along with the production time, according to the maximum monthly yield prediction model of the horizontal well to be drilled: qHmonth＝QHmax×tf；
In the formula, QHmaxThe maximum monthly oil production of the horizontal well to be drilled; t is the production time in months; qHmonthThe oil yield per month of the horizontal well to be drilled in the tth production time; f is a preset exponential constant, and the value of f is a negative value.
Because strong correlation exists between the maximum monthly yield of the drilled vertical well and the maximum monthly yield of the horizontal well to be drilled corresponding to the drilled vertical well, the embodiment of the invention is not based on the seepage theory any more, but utilizes objective and real drilled vertical well data to establish a maximum monthly yield prediction model of the drilled vertical well, then can obtain the maximum monthly yield prediction model of the horizontal well to be drilled corresponding to the drilled vertical well according to the model, and finally establishes a yield prediction model of the horizontal well to be drilled along with the production time according to the maximum monthly yield prediction model of the horizontal well to be drilled, so that the predicted oil gas yield of the horizontal well to be drilled along with the production time is more consistent with the actual production, thereby accurately predicting the oil gas yield of the horizontal well without oil testing.
Drawings
The accompanying drawings, which are included to provide a further understanding of the invention and are incorporated in and constitute a part of this application, illustrate embodiment(s) of the invention and together with the description serve to explain the principles of the invention. In the drawings:
FIG. 1 is a flow chart of a method for predicting oil and gas production of a horizontal well of a tight oil and gas reservoir according to an embodiment of the invention;
FIG. 2 shows the maximum oil and gas production per month and Q for a drilled vertical well according to an embodiment of the present inventionH/RSGraph of the relationship of (1);
FIG. 3 is a graph showing the relationship between the maximum oil production per month of a horizontal well at a position corresponding to a drilled vertical well in the embodiment of the invention;
fig. 4 is a graph of the monthly oil production of the horizontal well at the position corresponding to the drilled vertical well in the embodiment of the invention, which is in a decreasing relation with the production time.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, the present invention is further described in detail below with reference to the following embodiments and the accompanying drawings. The exemplary embodiments and descriptions of the present invention are provided to explain the present invention, but not to limit the present invention.
The following describes embodiments of the present invention in further detail with reference to the accompanying drawings.
Referring to fig. 1, the method for predicting the oil and gas production of the horizontal well of the tight oil and gas reservoir provided by the embodiment of the invention comprises the following steps:
step S101, establishing a reservoir structure index model and a capacity heterogeneous index model of the drilled vertical well according to the drilling data of the drilled vertical well.
The reserves of the compact oil and gas reservoir are closely related to the sand thickness and structure, the oil saturation, the porosity, the argillaceous content and the like, and the inventor of the invention finds that the correlation of the sand thickness, the structure and the change in the space can be described by utilizing the variation function. The variation function in case of discrete data is used:
in the formula, x is the direction of obtaining the variation function; h is a lag distance; n (h) is the logarithm of points at a spacing h; z (x)i) Is the value of a variable at a location; γ (h, x) is a variation function.
After the experimental variation function is solved, a spherical model can be adopted for fitting to discuss the space structure of the variable. The general calculation formula is:
in the formula C0The change of the variable value between two points when h is small is shown as the lump effect, C is the base value and reflects the variation degree of the variable in the research range, and α is the variation degree of a certain variable.
By fitting the theoretical variogram, the relevant parameters of the variogram can be determined. Usually, a variation function curve is adopted to discuss the space structure of a variable, when h < alpha, an observed value between any two points has correlation, and the correlation degree is reduced along with the increase of h; when h > α, there is no correlation anymore. The larger the value of alpha, the better the correlation of the explanatory variable in a certain direction; otherwise, the correlation is poor.
The formation of the variogram shows that it does not depend on the specific position of the variable in space, but only on its lag distance h and direction x. The logging curve and the geological variable obtained by the logging curve are taken as regional variables, and the reservoir logging curve and the geological variable which have differences in different thicknesses, structures, physical properties, oil contents and the like have obvious morphological characteristics, so that the variation difference in different directions is large, which indicates that the variation function can be applied to research the spatial correlation of the reservoir logging curve and the geological variable.
To better reflect the degree of correlation and deviation from the mean of the data in the longitudinal direction, a root function of variance is used, namely:
γS＝[γ(0.5×α)+γ(α)+S2]0.5
the reservoir structure form is closely related to a natural gamma logging curve and the distribution of the shale content, so that a reservoir structure index model can be established by utilizing a natural gamma variation variance root function and the shale content:
RS＝γS(GR)×VSh
in the formula RSIs a reservoir structural index; gamma rayS(GR) is the natural gamma variance root function; GR is the natural gamma log, API; vShIs the mud content, decimal.
The oil gas productivity of a compact reservoir is closely related to the variation variance root function of a density logging curve, the thickness of an oil gas layer, the porosity, the oil saturation, the formation pressure and the viscosity of crude oil, and a non-mean index model reflecting the crude oil productivity is established, namely the heterogeneous index of the crude oil productivity:
in the formula QHIs the non-average index of crude oil productivity; gamma rayS(DEN) is the root function of variance of the density log; hiIs the oil layer thickness of the ith layer, in m;is the porosity, decimal fraction, of the ith layer; soiIs the oil saturation, decimal, of the ith layer; giThe pressure gradient of the i layer is expressed in unit of MPa/100 m; mu.siCrude oil viscosity of the i-th layer is in units of mPa · s.
In this step, the inventor can establish a reservoir structure index model and a productivity heterogeneous index model of the drilled vertical well based on the analysis. Wherein the drilled vertical well is a compact oil-gas vertical well in the research area and is provided with an oil-gas pilot production data well section.
And S102, establishing a maximum monthly yield prediction model of the drilled vertical well by utilizing the reservoir structure index model and the productivity heterogeneous index model. In the embodiment of the invention, the model for predicting the maximum monthly yield of the drilled vertical well is as follows:
QVmax＝a×QH/RS+b；
in the formula, QVmaxThe maximum monthly oil production of the drilled vertical well; rSIs a reservoir structural index; qHIs the heterogeneous index of productivity; a is a preset coefficient; b is a preset constant.
And S103, establishing a maximum monthly yield prediction model of the horizontal well to be drilled at the position corresponding to the maximum monthly yield prediction model of the drilled vertical well according to the maximum monthly yield prediction model of the drilled vertical well. In the embodiment of the invention, the model for predicting the maximum monthly yield of the horizontal well to be drilled comprises the following steps:
QHmax＝c×QVmax d；
in the formula, QHmaxThe maximum monthly oil production of the horizontal well to be drilled; qVmaxThe maximum monthly oil production of the drilled vertical well; c is a preset coefficient; d is a preset exponential constant.
And S104, establishing a yield prediction model of the horizontal well to be drilled along with the production time according to the maximum monthly yield prediction model of the horizontal well to be drilled so as to predict the oil and gas yield of the horizontal well to be drilled along with the production time. The method specifically comprises the following steps:
establishing a prediction model of the horizontal well to be drilled, which changes in a descending rule along with the production time, according to the maximum monthly yield prediction model of the horizontal well to be drilled:
QHmonth＝QHmax×tf；
in the formula, QHmaxThe maximum monthly oil production of the horizontal well to be drilled; t is the production time in months; qHmonthThe oil yield per month of the horizontal well to be drilled in the tth production time; f is a preset exponential constant, and the value of f is a negative value.
The concrete application of the method for predicting the oil and gas yield of the horizontal well of the compact oil and gas reservoir of the embodiment of the invention is described by taking 7 sections of compact oil reservoirs of the Ordos basin extension group as an example:
the maximum monthly oil yield prediction model of a drilled vertical well A of the 7 sections of compact oil reservoirs in the Ordos basin extension group, which is established by the method for predicting the oil and gas yield of the horizontal well of the compact oil and gas reservoir in the embodiment of the invention, is as follows:
QVmax＝47.033×QH/RS-1.3611
combining the maximum oil and gas production per month and Q of the drilled vertical well A in FIG. 2H/RSThe relation curve graph shows that the coincidence rate of the relation curve and the actual well data of the drilled straight well A is high, and the complex correlation coefficient can reach 0.97.
The maximum monthly oil yield prediction model of the horizontal well B to be drilled at the position corresponding to the drilled vertical well A is as follows:
QHmax＝43.421×QVmax 0.4132
as can be known from the graph of fig. 3 showing the relationship between the maximum monthly oil production of the horizontal well at the position corresponding to the drilled vertical well, the maximum monthly oil production relationship curve of the horizontal well B and the actual well data of the horizontal well B have a high coincidence rate, and the complex correlation coefficient of the curve can reach 0.95.
The yield prediction model of the horizontal well B to be drilled along with the change of production time is as follows:
QHmonth＝615.0×t-0.028361
as can be seen from the graph of fig. 4 showing that the monthly oil production of the horizontal well at the position corresponding to the drilled vertical well decreases with the production time, 615 indicates the maximum monthly production of the horizontal well B, the predicted production of the horizontal well is 2.2319 ten thousand tons for the cumulative production of 195 months before the horizontal well, and the actual production of the subsequent horizontal well is 2.1831 ten thousand tons, which means that the calculated result coincidence rate is high.
After the oil and gas yield of the horizontal well to be drilled is obtained according to the method for predicting the oil and gas yield of the compact oil and gas reservoir horizontal well, which is disclosed by the embodiment of the invention, along with the change of the production time, the lower limit of the accumulative oil and gas economic yield can be determined according to the monthly running cost, the oil and gas price, the set lowest return on investment rate and the like of the horizontal well, when the oil and gas yield produced by one well from the beginning to the upper limit of the production time of the well is higher than the accumulative oil and gas economic yield, the well is an effective value well, the drilling of the horizontal well can be carried out, and on the contrary.
Because strong correlation exists between the maximum monthly output of the drilled vertical well and the maximum monthly output of the horizontal well to be drilled at the position corresponding to the drilled vertical well, the method for predicting the oil and gas output of the compact oil and gas reservoir horizontal well in the embodiment of the invention is not based on the seepage theory any more, but uses objective and real drilled vertical well data to establish a maximum monthly output prediction model of the drilled vertical well, then can obtain the maximum monthly output prediction model of the horizontal well to be drilled at the position corresponding to the drilled vertical well according to the model, and finally establishes a yield prediction model of the horizontal well to be drilled changing along with the production time according to the maximum monthly output prediction model of the horizontal well to be drilled, so that the predicted oil and gas output of the horizontal well to be drilled changing along with the production time is more consistent with the actual output.
Corresponding to the method for predicting the oil and gas yield of the compact oil and gas reservoir horizontal well in the embodiment of the invention, the device for predicting the oil and gas yield of the compact oil and gas reservoir horizontal well in the embodiment of the invention comprises a parameter model building module, a first yield model building module, a second yield model building module and an oil and gas yield prediction module. Wherein:
the parameter model establishing module is used for establishing a reservoir structure index model and a capacity heterogeneous index model of the drilled vertical well according to the drilling data of the drilled vertical well; see step S101 above for details.
The first yield model building module is used for building a maximum monthly yield prediction model of the drilled vertical well by utilizing the reservoir structure index model and the productivity heterogeneous index model; see step S102 above for details.
The second yield model establishing module is used for establishing a maximum monthly yield prediction model of the horizontal well to be drilled at the position corresponding to the maximum monthly yield prediction model of the drilled vertical well according to the maximum monthly yield prediction model of the drilled vertical well; see step S103 above for details.
And the oil and gas yield prediction module is used for establishing a yield prediction model of the horizontal well to be drilled along with the change of the production time according to the maximum monthly yield prediction model of the horizontal well to be drilled so as to predict the oil and gas yield of the horizontal well to be drilled along with the change of the production time. See step S104 above for details.
Because strong correlation exists between the maximum monthly output of the drilled vertical well and the maximum monthly output of the horizontal well to be drilled at the position corresponding to the drilled vertical well, the oil and gas output prediction device for the compact oil and gas reservoir horizontal well in the embodiment of the invention is not based on the seepage theory any more, but utilizes objective and real drilled vertical well data to establish a maximum monthly output prediction model of the drilled vertical well, then can obtain the maximum monthly output prediction model of the horizontal well to be drilled at the position corresponding to the drilled vertical well according to the model, and finally establishes a yield prediction model of the horizontal well to be drilled changing along with the production time according to the maximum monthly output prediction model of the horizontal well to be drilled, so that the predicted oil and gas output of the horizontal well to be drilled changing along with the production time is more consistent with the actual output.
Those of skill would further appreciate that the various illustrative logical blocks, units, and steps described in connection with the embodiments disclosed herein may be implemented as hardware, software, or combinations of both. Whether implemented in hardware or software depends upon the particular application and design requirements of the overall system. Skilled artisans may implement the described functionality in varying ways for each particular application, but such implementation decisions should not be interpreted as causing a departure from the scope of the present embodiments.
The various illustrative logical blocks, or elements, described in connection with the embodiments disclosed herein may be implemented or performed with a general purpose processor, a digital signal processor, an Application Specific Integrated Circuit (ASIC), a field programmable gate array or other programmable logic device, discrete gate or transistor logic, discrete hardware components, or any combination thereof designed to perform the functions described herein. A general-purpose processor may be a microprocessor, but in the alternative, the processor may be any conventional processor, controller, microcontroller, or state machine. A processor may also be implemented as a combination of computing devices, e.g., a digital signal processor and a microprocessor, a plurality of microprocessors, one or more microprocessors in conjunction with a digital signal processor core, or any other similar configuration.
The steps of a method or algorithm described in connection with the embodiments disclosed herein may be embodied directly in hardware, in a software module executed by a processor, or in a combination of the two. A software module may be stored in RAM memory, flash memory, ROM memory, EPROM memory, EEPROM memory, registers, hard disk, a removable disk, a CD-ROM, or any other form of storage medium known in the art. For example, a storage medium may be coupled to the processor such the processor can read information from, and write information to, the storage medium. In the alternative, the storage medium may be integral to the processor. The processor and the storage medium may reside in an ASIC, which may be located in a user terminal. In the alternative, the processor and the storage medium may reside in different components in a user terminal.
In one or more exemplary designs, the functions described above in connection with the embodiments of the invention may be implemented in hardware, software, firmware, or any combination of the three. If implemented in software, the functions may be stored on or transmitted over as one or more instructions or code on a computer-readable medium. Computer-readable media includes both computer storage media and communication media that facilitate transfer of a computer program from one place to another. Storage media may be any available media that can be accessed by a general purpose or special purpose computer. For example, such computer-readable media can include, but is not limited to, RAM, ROM, EEPROM, CD-ROM or other optical disk storage, magnetic disk storage or other magnetic storage devices, or any other medium which can be used to carry or store program code in the form of instructions or data structures and which can be read by a general-purpose or special-purpose computer, or a general-purpose or special-purpose processor. Additionally, any connection is properly termed a computer-readable medium, and, thus, is included if the software is transmitted from a website, server, or other remote source via a coaxial cable, fiber optic cable, twisted pair, Digital Subscriber Line (DSL), or wirelessly, e.g., infrared, radio, and microwave. Such discs (disk) and disks (disc) include compact disks, laser disks, optical disks, DVDs, floppy disks and blu-ray disks where disks usually reproduce data magnetically, while disks usually reproduce data optically with lasers. Combinations of the above may also be included in the computer-readable medium.
The above-mentioned embodiments are intended to illustrate the objects, technical solutions and advantages of the present invention in further detail, and it should be understood that the above-mentioned embodiments are only exemplary embodiments of the present invention, and are not intended to limit the scope of the present invention, and any modifications, equivalent substitutions, improvements and the like made within the spirit and principle of the present invention should be included in the scope of the present invention.
Claims (8)
1. A method for predicting oil and gas yield of a horizontal well of a compact oil and gas reservoir is characterized by comprising the following steps:
establishing a reservoir structure index model and a capacity heterogeneous index model of the drilled vertical well according to the drilling data of the drilled vertical well;
establishing a maximum monthly yield prediction model of the drilled vertical well by utilizing the reservoir structure index model and the productivity heterogeneous index model;
establishing a maximum monthly yield prediction model of the horizontal well to be drilled at the position corresponding to the model according to the maximum monthly yield prediction model of the drilled vertical well;
establishing a yield prediction model of the horizontal well to be drilled along with the production time according to the maximum monthly yield prediction model of the horizontal well to be drilled so as to predict the oil and gas yield of the horizontal well to be drilled along with the production time; wherein,
the reservoir structure index model is as follows: rS＝γS(GR)×VSh；
Wherein R isSIs a reservoir structural index; gamma rayS(GR) is the natural gamma variance root function; GR is a natural gamma logging value; vShIs the mud content;
the productivity heterogeneous index model comprises the following steps:
in the formula, QHIs the heterogeneous index of productivity; gamma rayS(DEN) is the root function of variance of the density log; hiThe thickness of the oil layer of the ith layer;porosity of the ith layer; soiIs the oil saturation of the ith layer; giIs the pressure gradient of the ith layer; mu.siIs the crude oil viscosity of the i-th layer.
2. The method for predicting the oil and gas production of the horizontal well of the tight oil and gas reservoir according to claim 1, wherein the model for predicting the maximum monthly production of the drilled vertical well is as follows: qV max＝a×QH/RS+b；
In the formula, QV maxThe maximum monthly oil production of the drilled vertical well; rSIs a reservoir structural index; qHIs the heterogeneous index of productivity; a is a preset coefficient; b is a preset constant.
3. The method for predicting hydrocarbon production of horizontal wells for tight hydrocarbon reservoirs according to claim 1, wherein the level to be drilled isThe model for predicting the maximum monthly yield of the well is: qH max＝c×QV max d；
In the formula, QH maxThe maximum monthly oil production of the horizontal well to be drilled; qV maxThe maximum monthly oil production of the drilled vertical well; c is a preset coefficient; d is a preset exponential constant.
4. The method for predicting oil and gas production of a tight oil and gas reservoir horizontal well according to claim 1,
the method for predicting the yield of the horizontal well to be drilled along with the production time comprises the following steps of establishing a yield prediction model of the horizontal well to be drilled along with the production time according to the maximum monthly yield prediction model of the horizontal well to be drilled, and specifically comprises the following steps:
establishing a prediction model of the horizontal well to be drilled, which changes in a descending rule along with the production time, according to the maximum monthly yield prediction model of the horizontal well to be drilled: qHmonth＝QH max×tf；
In the formula, QH maxThe maximum monthly oil production of the horizontal well to be drilled; t is the production time in months; qHmonthThe oil yield per month of the horizontal well to be drilled in the tth production time; f is a preset exponential constant, and the value of f is a negative value.
5. The utility model provides a prediction unit of tight oil and gas reservoir horizontal well oil and gas production which characterized in that includes:
the parameter model establishing module is used for establishing a reservoir structure index model and a capacity heterogeneous index model of the drilled vertical well according to the drilling data of the drilled vertical well;
the first yield model building module is used for building a maximum monthly yield prediction model of the drilled vertical well by utilizing the reservoir structure index model and the productivity heterogeneous index model;
the second yield model establishing module is used for establishing a maximum monthly yield prediction model of the horizontal well to be drilled at the position corresponding to the maximum monthly yield prediction model of the drilled vertical well according to the maximum monthly yield prediction model of the drilled vertical well;
the oil and gas yield prediction module is used for establishing a yield prediction model of the horizontal well to be drilled along with the change of production time according to the maximum monthly yield prediction model of the horizontal well to be drilled so as to predict the oil and gas yield of the horizontal well to be drilled along with the change of production time; wherein,
the reservoir structure index model is as follows: rS＝γS(GR)×VSh；
Wherein R isSIs a reservoir structural index; gamma rayS(GR) is the natural gamma variance root function; GR is a natural gamma logging value; vShIs the mud content;
the productivity heterogeneous index model comprises the following steps:
in the formula, QHIs the heterogeneous index of productivity; gamma rayS(DEN) is the root function of variance of the density log; hiThe thickness of the oil layer of the ith layer;porosity of the ith layer; soiIs the oil saturation of the ith layer; giIs the pressure gradient of the ith layer; mu.siIs the crude oil viscosity of the i-th layer.
6. The device for predicting the oil and gas production of the horizontal well for the tight oil and gas reservoir according to claim 5, wherein the model for predicting the maximum monthly production of the drilled vertical well is as follows: qV max＝a×QH/RS+b；
In the formula, QV maxThe maximum monthly oil production of the drilled vertical well; rSIs a reservoir structural index; qHIs the heterogeneous index of productivity; a is a preset coefficient; b is a preset constant.
7. The device for predicting the oil and gas production of the tight oil and gas reservoir horizontal well according to claim 5, wherein the model for predicting the maximum monthly production of the horizontal well to be drilled is as follows: qH max＝c×QV max d；
In the formula, QH maxThe maximum monthly oil production of the horizontal well to be drilled; qV maxThe maximum monthly oil production of the drilled vertical well; c is a preset coefficient; d is a preset exponential constant.
8. The tight hydrocarbon reservoir horizontal well hydrocarbon production prediction device of claim 5,
the method for predicting the yield of the horizontal well to be drilled along with the production time comprises the following steps of establishing a yield prediction model of the horizontal well to be drilled along with the production time according to the maximum monthly yield prediction model of the horizontal well to be drilled, and specifically comprises the following steps:
establishing a prediction model of the horizontal well to be drilled, which changes in a descending rule along with the production time, according to the maximum monthly yield prediction model of the horizontal well to be drilled: qHmonth＝QH max×tf；
In the formula, QH maxThe maximum monthly oil production of the horizontal well to be drilled; t is the production time in months; qHmonthThe oil yield per month of the horizontal well to be drilled in the tth production time; f is a preset exponential constant, and the value of f is a negative value.
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