CN115936232A - Method and system for predicting density and encryption adjustment time of reasonable well pattern of tight gas reservoir - Google Patents
Method and system for predicting density and encryption adjustment time of reasonable well pattern of tight gas reservoir Download PDFInfo
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Abstract
The invention discloses a method and a system for predicting reasonable well pattern density and encryption adjusting time of a tight gas reservoir. The method comprises the following steps: determining the reasonable well pattern density of the sand body to be predicted according to the logging permeability and the reserve abundance of the sand body to be predicted and a pre-established reasonable well pattern density prediction chart of the tight gas reservoir; and if the sand body to be predicted has the encryption condition, determining the encryption adjustment time of the sand body to be predicted according to the logging permeability and the reserve abundance of the sand body to be predicted and a pre-established compact gas reservoir encryption adjustment time prediction chart. The method can be used for quickly predicting reasonable well pattern density and encryption adjustment time on the basis of known sand logging permeability and reserve abundance, and can be widely applied to the field of exploration and development of tight gas reservoirs.
Description
Technical Field
The invention relates to the field of exploration and development of tight gas reservoirs, in particular to a method and a system for predicting reasonable well pattern density and encryption adjustment time of a tight gas reservoir.
Background
In recent years, the oil and gas resources in China have entered the development stage of conventional and unconventional reduplication, and the unconventional oil and gas accounts for 41 percent of the nationwide cumulative proven oil and gas reserves; the unconventional oil gas accounts for 20% of the total oil gas yield, the dense gas becomes an important component for replacing the unconventional oil gas yield, and the exploration and development potential is huge.
However, due to the characteristics of low permeability, strong heterogeneity, small effective spread range, low reserve utilization degree and the like of the reservoir stratum of the compact gas reservoir, the density of the developed well pattern is a main influence factor of the extraction degree of the compact gas reservoir; the density of the well pattern is too small, the well pattern has insufficient control degree on the reserves due to poor continuity and strong heterogeneity of the plane, the reserves are difficult to be fully used, and the final extraction degree of the gas reservoir is low; if the density of the well pattern is too high, the inter-well interference tends to be serious, and although the production degree can be further improved, the economic benefit is difficult to ensure; when the density of the well pattern is increased, the time for deploying the encryption well also directly influences the yield increasing effect;
the prior art method is not economical nor applicable to the evaluation of reasonable well pattern density and encryption adjusting time of reservoirs with different physical properties of the compact gas reservoir. Therefore, the accurate and rapid determination of the reasonable well pattern density and the encryption adjustment time of the reservoirs with different physical properties of the tight gas reservoir has great significance for the economic and effective development of the tight gas reservoir.
Disclosure of Invention
In view of the above problems, the present invention aims to provide a prediction method and system capable of accurately and quickly determining reasonable well pattern density and encryption adjustment time of sand bodies with different physical properties in a tight gas reservoir.
In order to achieve the purpose, the invention adopts the following technical scheme:
in a first aspect, the present invention provides a method for predicting a reasonable well pattern density and an encryption adjustment time of a tight gas reservoir, comprising:
determining the reasonable well pattern density of the sand body to be predicted according to the logging permeability and the reserve abundance of the sand body to be predicted and a pre-established reasonable well pattern density prediction chart of the dense gas reservoir;
and if the sand body to be predicted has the encryption condition, determining the encryption adjustment time of the sand body to be predicted according to the logging permeability and the reserve abundance of the sand body to be predicted and a pre-established compact gas reservoir encryption adjustment time prediction chart.
In the method for predicting the reasonable well pattern density of the tight gas reservoir and the encryption adjusting time, the abscissa of the prediction chart of the reasonable well pattern density of the tight gas reservoir is the logging permeability of the sand body to be predicted, the ordinate is the reasonable well pattern density of the sand body to be predicted, and different curves in the chart represent the relationship between the logging permeability and the reasonable well pattern density under different reserves and abundances.
Furthermore, the compact gas reservoir reasonable well pattern density prediction plate is established by simulating the relationship between the well pattern densities and the well pattern density evaluation indexes under different permeability and reserve abundance based on a numerical model and determining the reasonable well pattern densities under different permeability and reserve abundance by using the well pattern density evaluation index standard.
Furthermore, the numerical model is established based on geological characteristic parameters of the near-interest dense sandstone gas reservoir;
the well pattern density evaluation index comprises the average single well yield of the single well economic benefit of the dense gas reservoir evaluation and the extraction degree increment of the overall economic benefit;
the well pattern density evaluation index standard is established according to the development economy of the tight gas reservoir, namely the average single well yield is larger than or equal to the lowest average single well yield of a common well, and the extraction degree increment is larger than or equal to the extraction degree increment threshold;
wherein the lowest average single well production = average single well combined investment ÷ (gas price-combined operating fee-unit tax);
production degree increment threshold = (abundance of reserves ÷ 1.2) × (7.5%);
wherein the calculation formula of the average single-well comprehensive investment is as follows:
the average single well comprehensive investment of a common well = drilling and completion cost + ground engineering construction cost;
average single well combined investment for infill wells = well completion cost.
In the method for predicting the reasonable well pattern density and the encryption adjustment time of the tight gas reservoir, when the area of (the actual well number of sand bodies + 1) ÷ sand bodies is less than or equal to the predicted reasonable well pattern density, the sand bodies to be predicted have the encryption condition;
the abscissa of the compact gas reservoir encryption adjustment time prediction chart is the well logging permeability of the sand body to be predicted, the ordinate is the sand body encryption adjustment time to be predicted, and different curves in the chart represent the relationship between the well logging permeability and the encryption adjustment time under different reserves and abundances;
the adjusting time refers to the extraction degree of sand bodies when the encryption well is deployed;
the encryption adjusting time refers to the maximum sand body extraction degree of the encryption well which can be deployed;
when the actual extraction degree of the sand body is less than or equal to the predicted encryption adjusting time when the sand body is deployed in the encryption well, representing that the sand body can be currently deployed in the encryption well; and when the actual production degree is larger than the predicted encryption adjusting time when the sand body is deployed in the encryption well, the sand body is not suitable for deploying the encryption well at present.
Further, the compact gas reservoir encryption adjustment opportunity prediction chart is established by simulating the relationship between adjustment opportunities at different permeabilities and reserve abundances and adjustment opportunity evaluation indexes based on a numerical model, and determining encryption adjustment opportunities at different permeabilities and reserve abundances by using adjustment opportunity evaluation index standards.
Furthermore, the numerical model is established on the basis of geological characteristic parameters of the clinical delightful dense sandstone gas reservoir;
and the adjustment time evaluation index is the accumulated gas production increment of the sand body after the compact gas reservoir is deployed in the encrypted well.
The adjustment opportunity evaluation index standard is established according to the development economy of the compact gas reservoir, namely the accumulated gas production increment of sand bodies after the encryption wells are deployed is larger than or equal to the lowest average single well yield of the encryption wells;
wherein the lowest average single well production = average single well integrated investment ÷ (gas price-integrated operating fee-unit tax fund);
wherein the calculation formula of the average single-well comprehensive investment is as follows:
the average single-well comprehensive investment of a common well = drilling and completion expense + ground engineering construction expense;
average single well combined investment for infill wells = well completion cost.
In a second aspect, the present invention provides a system for predicting a reasonable well pattern density and an encryption adjustment time of a tight gas reservoir, comprising:
the reasonable well pattern density prediction module is used for determining the reasonable well pattern density of the sand body to be predicted according to the logging permeability and the reserve abundance of the sand body to be predicted and a pre-established reasonable well pattern density prediction chart of the compact gas reservoir;
and the encryption adjusting time predicting module is used for determining the encryption adjusting time of the sand body to be predicted according to the logging permeability and the reserve abundance of the sand body to be predicted and a pre-established compact gas reservoir encryption adjusting time predicting plate.
In a third aspect, the present invention provides a processing apparatus, comprising a memory, a processor and a computer program stored in the memory and executable on the processor, wherein the processor when executing the computer program implements the steps corresponding to the tight gas reservoir reasonable well pattern density and encryption adjustment timing prediction method as described in any one of the above.
In a fourth aspect, the present invention provides a computer readable storage medium, having computer program instructions stored thereon, wherein the computer program instructions, when executed by a processor, are configured to implement the steps corresponding to any one of the methods for predicting a tight gas reservoir reasonable well pattern density and an encryption adjustment timing.
Due to the adoption of the technical scheme, the invention has the following advantages:
1. according to the method, the well pattern density can be rapidly predicted according to the established reasonable well pattern density prediction plate on the basis of the known sand body permeability and the reserve abundance, the prediction speed is obviously improved compared with the traditional well pattern density evaluation method, the prediction deviation caused by inaccurate values of the traditional method is avoided, and the result is more real, accurate and credible.
2. The method can quickly predict the encryption adjusting time according to the established encryption adjusting time prediction plate on the basis of the known sand body permeability and the reserve abundance, obviously improves the prediction speed, avoids the prediction deviation caused by inexperience and increases the accuracy of the prediction result compared with the traditional method for determining the time for deploying the encryption well according to experience.
In conclusion, the method can be widely applied to the field of exploration and development of the tight gas reservoir.
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Various additional advantages and benefits will become apparent to those of ordinary skill in the art upon reading the following detailed description of the preferred embodiments. The drawings are only for purposes of illustrating the preferred embodiments and are not to be construed as limiting the invention. Like reference numerals refer to like parts throughout the drawings. In the drawings:
FIG. 1 is a schematic flow chart of a method provided by an embodiment of the present invention;
FIG. 2 is a compact gas reservoir rational well pattern density prediction template provided by an embodiment of the invention;
FIG. 3 is a block diagram of a compact gas pool encryption timing prediction scheme according to an embodiment of the present invention;
FIG. 4 is a process for determining a reasonable pattern density in a plot of evaluation indicators versus pattern density using evaluation indicator criteria as provided by an embodiment of the present invention;
fig. 5 is a process of determining an encryption adjustment timing in a curve relating evaluation indexes to adjustment timings according to an evaluation index standard according to an embodiment of the present invention.
Detailed Description
In the following description, for purposes of explanation and not limitation, specific details are set forth such as particular system structures, techniques, etc. in order to provide a thorough understanding of the embodiments of the present application. It will be apparent, however, to one skilled in the art that the present application may be practiced in other embodiments that depart from these specific details. In other instances, detailed descriptions of well-known systems, devices, circuits, and methods are omitted so as not to obscure the description of the present application with unnecessary detail.
It is to be understood that the terminology used herein is for the purpose of describing particular example embodiments only, and is not intended to be limiting. As used herein, the singular forms "a", "an" and "the" may be intended to include the plural forms as well, unless the context clearly indicates otherwise. The terms "comprises," "comprising," "including," and "having" are inclusive and therefore specify the presence of stated features, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, steps, operations, elements, components, and/or groups thereof. The method steps, processes, and operations described herein are not to be construed as necessarily requiring their performance in the particular order described or illustrated, unless specifically identified as an order of performance. It should also be understood that additional or alternative steps may be used.
Aiming at the problem that the reasonable well pattern density and the encryption adjusting time of sand bodies with different physical properties cannot be accurately and quickly evaluated in a compact gas reservoir, the method and the system for predicting the reasonable well pattern density and the encryption adjusting time of the compact gas reservoir provided by the embodiment of the invention can accurately and quickly determine the reasonable well pattern density and the encryption adjusting time of the sand body to be predicted finally based on the pre-established reasonable well pattern density prediction plate and the encryption adjusting time prediction plate of the compact gas reservoir. In order to illustrate the technical means of the present invention, the following description is given by way of specific examples.
Example 1
As shown in fig. 1, the present embodiment provides a method for predicting a reasonable pattern density and a timing for adjusting encryption of a tight gas reservoir, which may include the following steps:
1) And determining the reasonable well pattern density of the sand body to be predicted according to the logging permeability and the reserve abundance of the sand body to be predicted and a pre-established reasonable well pattern density prediction chart of the compact gas reservoir.
Specifically, a compact gas reservoir reasonable well pattern density prediction plate is shown in fig. 2, the abscissa is the well logging permeability of the sand body to be predicted, the ordinate is the reasonable well pattern density of the sand body to be predicted, and different curves in the plate represent the relationship between the well logging permeability and the reasonable well pattern density under different reserves and abundances.
Specifically, when the actual well pattern density of the sand body is less than or equal to the predicted reasonable well pattern density, the sand body production effect is better; and when the actual well pattern density of the sand body is larger than the predicted reasonable well pattern density, the sand body production effect is poor.
2) If the sand body to be predicted has the encryption condition, determining the encryption adjustment time of the sand body to be predicted (namely the maximum extraction degree of the sand body to be predicted, which can be deployed in the encryption well) according to the logging permeability and the reserve abundance of the sand body to be predicted and a pre-established compact gas reservoir encryption adjustment time prediction chart.
Specifically, when the area of the sand body is less than or equal to the predicted reasonable well pattern density (the actual well number of the sand body is + 1), the sand body has the encryption condition and can be encrypted.
Specifically, a tight gas reservoir encryption adjustment timing prediction chart is shown in fig. 3, the abscissa represents the logging permeability of the sand body to be predicted, the ordinate represents the encryption adjustment timing of the sand body to be predicted, and different curves in the chart represent the relationship between the logging permeability and the encryption adjustment timing under different reserves abundance.
Specifically, when the actual production degree is less than or equal to the predicted encryption adjustment time when the sand body is deployed in the encryption well, the sand body can be currently deployed in the encryption well, and the yield increasing effect of the encryption well is good; and when the actual production degree is larger than the predicted encryption adjusting time when the sand body is deployed in the encryption well, the sand body is not suitable for deploying the encryption well at present.
In the above embodiment, preferably, in step 1), the tight gas reservoir reasonable well pattern density prediction template is created by simulating a relationship between well pattern densities and well pattern density evaluation indexes at different permeabilities and reserve abundances based on a numerical model, and determining and establishing the reasonable well pattern densities at different permeabilities and reserve abundances by using an evaluation index standard.
Specifically, the numerical model is established based on geological characteristic parameters of the near-interest dense sandstone gas reservoir; specifically, the PEBI grid used for the numerical model simulates a sand body, and the model has the size of 1440m multiplied by 700m and the area of 1km 2 The original formation pressure is 15.0MPa, the porosity is 11%, the permeability is 0.4mD-2.0mD, the gas saturation is 55%, and the reserve abundance is 0.5 multiplied by 10 8 m 3 /km 2 -2.0×10 8 m 3 /km 2 (ii) a Different well pattern densities are simulated by controlling the production wells on the model, and the production wells under the different well pattern densities are uniformly distributed on the model.
Specifically, the evaluation indexes comprise average single-well yield of the compact gas reservoir evaluation single-well economic benefit and extraction degree increment of the overall economic benefit. The standard is established according to the development economy of the compact gas reservoir, namely the average single-well yield is more than or equal to the lowest average single-well yield of a common well, and the extraction degree increment is more than or equal to the extraction degree increment threshold;
wherein the lowest average single well production = average single well combined investment ÷ (gas price-combined operating fee-unit tax);
wherein the gas value is 1m 3 The sale price of natural gas is 1m of the comprehensive operation cost 3 Cost of natural gas, unit tax is 1m 3 The natural gas needs to pay tax amount;
production degree increment threshold = (abundance of reserves ÷ 1.2) × (7.5%);
the calculation formula of the average single-well comprehensive investment is as follows:
the average single-well comprehensive investment of a common well = drilling and completion expense + ground engineering construction expense;
average individual well composite investment of infill wells = well completion cost.
Controlling the abundance of the reserves to be 1.2 multiplied by 10 by using the numerical model 8 m 3 /km 2 The permeability is 0.4mD, and the final accumulated gas production rate and the final extraction degree of the model under different well pattern densities can be obtained through simulation by changing the number of production wells of the model;
the method comprises the following steps of evaluating the average single well yield when the well pattern density is i = the accumulated gas production when the well pattern density is i ÷ the number of production wells when the well pattern density is i =1, 2, 3 and 4.;
in the evaluation index, the production degree increment when the well pattern density is i = the production degree when the well pattern density is i-the production degree when the well pattern density is (i-1), i =2, 3, 4, 5;
under the current gas price condition and the reserve abundance, the lowest average single well yield of the common well is calculated to be 1600 multiplied by 10 4 m 3 The extraction degree increment threshold is 7.5%; namely the evaluation index standard is that the average single well yield is more than or equal to 1600 multiplied by 10 4 m 3 And the extraction degree increment is more than or equal to 7.5 percent;
the relationship between the obtained evaluation index and the well pattern density is drawn as a graph, and as shown in figure 4, the abundance of the reserve is determined to be 1.2 multiplied by 10 by using the evaluation index standard 8 m 3 /km 2 When the permeability is 0.4mD, the reasonable well pattern density is 4.1 ports/km 2 。
By controlling the reserves abundance to be unchanged, changing the permeability and repeating the process, the reasonable well pattern density corresponding to different permeability under the same reserves abundance can be obtained;
by changing the reserve abundance, the reasonable well pattern density corresponding to different permeability under different reserve abundances can be obtained by repeating the process.
The relationship between the reasonable well pattern density of the sand bodies and the different permeability and reserve abundance is shown in the table 1.
TABLE 1 reasonable well pattern Density relationship of different Permeability and reserve abundance to Sand bodies
In the above embodiment, preferably, in step 2), the tight gas reservoir encryption adjustment timing prediction chart is obtained by simulating a relationship between adjustment timings and adjustment timing evaluation indexes at different permeabilities and reserve abundances based on a numerical model under the condition that sand bodies have encryption, and determining a relationship between encryption adjustment timings at different permeabilities and reserve abundances by using an adjustment timing evaluation index standard.
Specifically, adjusting the timing refers to the production level of sand bodies when the infill well is deployed.
Specifically, the timing of encryption adjustment refers to the maximum sand production level at which the encryption wells can be deployed.
Specifically, the numerical model is established based on geological characteristic parameters of the near-interest dense sandstone gas reservoir; specifically, the PEBI grid used for the numerical model simulates a sand body, and the model has the size of 1440m multiplied by 700m and the area of 1km 2 The original formation pressure is 15.0MPa, the porosity is 11%, the permeability is 0.4mD-2.0mD, the gas saturation is 55%, and the reserve abundance is 1.2 multiplied by 10 8 m 3 /km 2 -2.0×10 8 m 3 /km 2 (ii) a Three wells are uniformly arranged on the model, the encrypted wells are simulated and deployed by controlling the well opening time of the middle well, and the extraction degree of the model is the adjusting time when the middle well is opened.
Specifically, the opportunity evaluation index is adjusted to be the accumulated gas production increment of the sand body after the dense gas reservoir is deployed in the encrypted well.
Specifically, the time adjustment evaluation index standard is established according to the development economy of the compact gas reservoir, namely the accumulated gas production increment of sand bodies after the encrypted wells are deployed is larger than or equal to the lowest average single well yield of the encrypted wells;
wherein the lowest average single well production = average single well combined investment ÷ (gas price-combined operating fee-unit tax);
wherein the gas value is 1m 3 The sale price of natural gas is 1m of the comprehensive operation cost 3 Cost of natural gas, unit tax is 1m 3 The natural gas needs to pay tax amount;
wherein the calculation formula of the average single-well comprehensive investment is as follows:
the average single well comprehensive investment of a common well = drilling and completion cost + ground engineering construction cost;
average individual well composite investment of infill wells = well completion cost.
Controlling the abundance of reserves to be 1.2 multiplied by 10 by using the numerical model 8 m 3 /km 2 And a permeability of 0.4mD to 1.0mD (as can be seen from Table 1, the permeability is greater than 1 at this abundance0mD does not have encryption conditions), and the final accumulated gas production rate of the model at different adjusting occasions can be obtained by simulating the well opening time of the middle well;
evaluating indexes, namely the accumulated gas yield increment after the arrangement of the encryption well = the final accumulated gas yield of the encryption well model arranged under different adjusting occasions-the final accumulated gas yield of the encryption well model not arranged;
under the current gas price condition, the lowest average single well yield of the encrypted well is calculated to be 1100 multiplied by 10 4 m 3 Namely, the evaluation index standard is that the accumulated gas production increment of the sand body after the encrypted well is deployed is more than or equal to 1100 multiplied by 10 4 m 3 ；
The relationship between the evaluation index and the adjustment timing obtained above is plotted, and as shown in FIG. 5, the abundance of the reserve can be determined to be 1.2X 10 by using the evaluation index standard 8 m 3 /km 2 Time, encryption adjustment opportunity at different permeabilities;
by changing the reserves abundance, the encryption adjusting time corresponding to different permeability under different reserves abundance can be obtained by repeating the process;
the established relationship between different permeability and reserve abundance and the encryption adjustment timing of sand bodies is shown in table 2.
TABLE 2 relationship of different permeabilities and reserve abundances to sand encryptions adjustment timing
The method for predicting the density of the reasonable well pattern of the tight gas reservoir is explained in detail by the following specific examples:
the actual well pattern density of the sand body A is 2.9 openings/km 2 Permeability K is 1.0mD, and reserve abundance is 1.05X 10 8 m 3 /km 2 (ii) a The actual well pattern density of the sand body B is 3.0 openings/km 2 Permeability K is 2.0mD and reserve abundance is 1.26X 10 8 m 3 /km 2 ；
According to a pre-established compact gas reservoir reasonable well pattern density prediction chart, the permeability K of the sand body A is 1.0mD, and the reserve abundance is 1.05 multiplied by 10 8 m 3 /km 2 The density of the well pattern is found to be 3.0 openings/km 2 (ii) a The permeability K of the sand body B is 2.0mD, and the reserve abundance is 1.26 multiplied by 10 8 m 3 /km 2 The density of the well pattern is found to be 2.0 openings/km 2 。
Actual well pattern density of sand body A is 2.9 openings/km 2 Less than predicted reasonable well pattern density of 3.0 openings/km 2 Well pattern density is in reasonable range and average single well production of sand body A is 1890X 10 4 m 3 Mean minimum single well production of 1600X 10 over the average well 4 m 3 Therefore, the production effect is better; actual well pattern density of sand body B is 3.0 openings/km 2 More than predicted reasonable well pattern density 2.0 hole/km 2 The well pattern density is unreasonable, and the average single well production of sand body B is 1143 multiplied by 10 4 m 3 Minimum average single well production of 1600 x 10 less than the average well 4 m 3 Therefore, the production effect is poor. The prediction result is consistent with the actual production result, and the method provided by the embodiment of the invention is proved to have higher precision, can greatly improve the prediction speed, and can quickly determine the number of deployed wells according to the physical properties of sand bodies during the scheme preparation.
The method for predicting the time for adjusting the encryption of the dense gas reservoir is described in detail through another specific implementation:
the sand body C has the encryption condition (the actual well number of the sand body is 1, the sand body area is 0.90km 2 And through calculation, (the actual well number of the sand body is plus 1) ÷ the area of the sand body is less than or equal to the predicted reasonable well pattern density, so that the sand body C has an encryption condition), the production degree is 6.8 percent during actual encryption, the permeability is 1.2mD, and the reserve abundance is 1.54 multiplied by 10 8 m 3 /km 2 (ii) a The sand body D has the encryption condition (the actual well number of the sand body is 1, the sand body area is 0.66km 2 The calculation shows that (the actual well number of sand bodies is plus 1 divided by the area of the sand bodies is not more than the predicted reasonable well pattern density, so that the sand bodies D have the encryption condition), the production degree is 34 percent during actual encryption, the permeability is 1.5mD, and the reserve abundance is 1.42 multiplied by 10 8 m 3 /km 2 ；
According to a pre-established compact gas reservoir encryption adjusting time prediction chart, the permeability of the sand body C is 1.2mD, and the reserve abundance is 1.5410 8 m 3 /km 2 Checking the encryption adjusting time to be 30%; the sand body D has a permeability K of 1.5mD and a reserve abundance of 1.42 multiplied by 10 8 m 3 /km 2 And the encryption adjusting time is found to be 24%.
The actual adjustment time of the sand body C is 6.8 percent and is less than the predicted encryption adjustment time 30 percent, the encryption well is arranged in the recommended encryption adjustment time, and the accumulated gas production increment after the sand body C is arranged in the encryption well is 1300 multiplied by 10 4 m 3 1100X 10 above the minimum average single well production for the infill well 4 m 3 Therefore, the production effect of the encrypted well is better; the actual adjustment time of the sand body D is 34 percent more than the predicted encryption adjustment time 24 percent, the encryption well is arranged outside the machine when the encryption adjustment is recommended, and the accumulated gas production increment after the sand body D is arranged in the encryption well is 650 multiplied by 10 4 m 3 Less than 1100 x 10 minimum average individual well production for infill wells 4 m 3 Therefore, the production effect of the encrypted well is poor. The prediction result is consistent with the actual production result, and the method provided by the embodiment of the invention is proved to have higher precision, can greatly improve the prediction speed, and can quickly determine the encryption adjustment time according to the physical properties of sand bodies when the encryption well is deployed.
Example 2
The embodiment provides a system for predicting reasonable well pattern density and encryption adjusting time of a tight gas reservoir, which comprises:
and the reasonable well pattern density prediction module is used for determining the reasonable well pattern density of the sand body to be predicted according to the physical property of the sand body to be predicted and a pre-established reasonable well pattern density prediction chart of the dense gas reservoir.
And the encryption adjusting time predicting module is used for determining the encryption adjusting time of the sand body to be predicted according to the physical property of the sand body to be predicted and a pre-established compact gas reservoir encryption adjusting time predicting plate.
The system provided in this embodiment is used for executing the above method embodiments, and for details of the process and the details, reference is made to the above embodiments, which are not described herein again.
The system provided by this embodiment may be a software unit, a hardware unit, or a unit combining software and hardware that is built in the existing terminal device, may also be integrated into the terminal device as an independent pendant, and may also exist as an independent terminal device.
It will be apparent to those skilled in the art that, for convenience and brevity of description, only the above-mentioned division of the functional units and modules is illustrated, and in practical applications, the above-mentioned function distribution may be performed by different functional units and modules according to needs, that is, the internal structure of the apparatus is divided into different functional units or modules to perform all or part of the above-mentioned functions. Each functional unit and module in the embodiments may be integrated in one processing unit, or each unit may exist alone physically, or two or more units are integrated in one unit, and the integrated unit may be implemented in a form of hardware, or in a form of software functional unit. In addition, specific names of the functional units and modules are only for convenience of distinguishing from each other, and are not used for limiting the protection scope of the present application. The specific working processes of the units and modules in the system may refer to the corresponding processes in the foregoing method embodiments, and are not described herein again.
Example 3
The present embodiment provides a processing device corresponding to the method for predicting the capacity of a tight gas well provided in embodiment 1, where the processing device may be a processing device for a client, such as a mobile phone, a laptop, a tablet computer, a desktop computer, etc., so as to execute the method in embodiment 1.
The processing equipment comprises a processor, a memory, a communication interface and a bus, wherein the processor, the memory and the communication interface are connected through the bus so as to complete mutual communication. The memory stores a computer program operable on the processing device, and the processing device executes the steps of the method for predicting the capacity of the tight gas well provided in embodiment 1 when running the computer program.
In some implementations, the Memory may be a high-speed Random Access Memory (RAM), and may also include non-volatile Memory (non-volatile Memory), such as at least one disk Memory.
In other implementations, the Processor may be a Central Processing Unit (CPU), other general purpose Processor, a Digital Signal Processor (DSP), an Application Specific Integrated Circuit (ASIC), a Field-Programmable Gate Array (FPGA) or other Programmable logic device, discrete Gate or transistor logic, discrete hardware components, or the like. The general purpose processor may be a microprocessor or the processor may be any conventional processor and the like, and is not limited herein.
In addition, the logic instructions in the memory may be implemented in the form of software functional units and may be stored in a computer readable storage medium when sold or used as a stand-alone product. Based on such understanding, the technical solution of the present invention or a part thereof which substantially contributes to the prior art may be embodied in the form of a software product, which is stored in a storage medium and includes several instructions for causing a computer device (which may be a personal computer, a server, or a network device) to execute all or part of the steps of the method according to the embodiments of the present invention. And the aforementioned storage medium includes: a U-disk, a removable hard disk, a Read-Only Memory (ROM), a Random Access Memory (RAM), a magnetic disk, or an optical disk, and various media capable of storing program codes.
Those skilled in the art will appreciate that the above-described configurations of computing devices are merely some of the configurations associated with the present application and do not constitute limitations on the computing devices to which the present application may be applied, as a particular computing device may include more or fewer components, or some components in combination, or have a different arrangement of components.
Example 4
This embodiment provides a computer program product corresponding to the method for predicting the capacity of a tight gas well provided in this embodiment 1, and the computer program product may include a computer readable storage medium having computer readable program instructions for executing the method for predicting the capacity of a tight gas well described in this embodiment 1.
The computer readable storage medium may be a tangible device that retains and stores instructions for use by an instruction execution device. The computer readable storage medium may be, for example, but not limited to, an electronic memory device, a magnetic memory device, an optical memory device, an electromagnetic memory device, a semiconductor memory device, or any combination of the foregoing.
The implementation principle and technical effect of the computer-readable storage medium provided by the above embodiments are similar to those of the above method embodiments, and are not described herein again.
The present invention is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the application. It will be understood that each flow and/or block of the flowchart illustrations and/or block diagrams, and combinations of flows and/or blocks in the flowchart illustrations and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
The above-mentioned embodiments are only used for illustrating the technical solutions of the present application, and not for limiting the same; although the present application has been described in detail with reference to the foregoing embodiments, it should be understood by those of ordinary skill in the art that: the technical solutions described in the foregoing embodiments may still be modified, or some technical features may be equivalently replaced; such modifications and substitutions do not depart from the spirit and scope of the embodiments of the present application, and they should be construed as being included in the present application.
Claims (10)
1. A method for predicting reasonable well pattern density and encryption adjustment time of a tight gas reservoir is characterized by comprising the following steps:
determining the reasonable well pattern density of the sand body to be predicted according to the logging permeability and the reserve abundance of the sand body to be predicted and a pre-established reasonable well pattern density prediction chart of the dense gas reservoir;
and if the sand body to be predicted has the encryption condition, determining the encryption adjustment time of the sand body to be predicted according to the logging permeability and the reserve abundance of the sand body to be predicted and a pre-established compact gas reservoir encryption adjustment time prediction chart.
2. The method for predicting the reasonable well pattern density and the time for adjusting the encryption of the tight gas reservoir according to claim 1, wherein the method comprises the following steps: the abscissa of the compact gas reservoir reasonable well pattern density prediction plate is the well logging permeability of the sand body to be predicted, the ordinate is the reasonable well pattern density of the sand body to be predicted, and different curves in the plate represent the relationship between the well logging permeability and the reasonable well pattern density under different reserves and abundances.
3. The method for predicting the reasonable well pattern density and the encryption adjusting time of the tight gas reservoir according to claim 1 or 2, wherein the reasonable well pattern density and the encryption adjusting time are as follows: the compact gas reservoir reasonable well pattern density prediction plate is established by simulating the relationship between the well pattern densities and well pattern density evaluation indexes under different permeability and reserve abundance based on a numerical model and determining the reasonable well pattern densities under different permeability and reserve abundance by using a well pattern density evaluation index standard.
4. The method for predicting the reasonable well pattern density and the time for adjusting the encryption of the tight gas reservoir according to claim 3, wherein the reasonable well pattern density and the time for adjusting the encryption are as follows: the numerical model is established on the basis of geological characteristic parameters of the near-interest dense sandstone gas reservoir;
the well pattern density evaluation index comprises the average single well yield of the single well economic benefit of the dense gas reservoir evaluation and the extraction degree increment of the overall economic benefit;
the well pattern density evaluation index standard is established according to the development economy of the tight gas reservoir, namely the average single well yield is larger than or equal to the lowest average single well yield of a common well, and the extraction degree increment is larger than or equal to the extraction degree increment threshold;
wherein the lowest average single well production = average single well combined investment ÷ (gas price-combined operating fee-unit tax);
production degree increment threshold = (abundance of reserves ÷ 1.2) × (7.5%);
wherein the calculation formula of the average single-well comprehensive investment is as follows:
the average single well comprehensive investment of a common well = drilling and completion cost + ground engineering construction cost;
average single well combined investment for infill wells = well completion cost.
5. The method for predicting the reasonable well pattern density and the time for adjusting the encryption of the tight gas reservoir according to claim 1, wherein the method comprises the following steps: when the area of the sand body is less than or equal to the predicted reasonable well pattern density (the actual well number of the sand body is plus 1), representing that the sand body to be predicted has an encryption condition;
the abscissa of the compact gas reservoir encryption adjustment time prediction chart is the well logging permeability of the sand body to be predicted, the ordinate is the sand body encryption adjustment time to be predicted, and different curves in the chart represent the relationship between the well logging permeability and the encryption adjustment time under different reserves and abundances;
the adjusting time refers to the extraction degree of sand bodies when the encryption well is deployed;
the encryption adjusting time refers to the maximum sand body extraction degree of the encryption well which can be deployed;
when the actual extraction degree of the sand body is less than or equal to the predicted encryption adjusting time when the sand body is deployed in the encryption well, representing that the sand body can be currently deployed in the encryption well; and when the actual production degree is larger than the predicted encryption adjusting time when the sand body is deployed in the encryption well, the sand body is not suitable for deploying the encryption well at present.
6. The method for predicting the reasonable well pattern density and the time for adjusting the encryption of the tight gas reservoir according to claim 1 or 5, wherein the method comprises the following steps: the compact gas reservoir encryption adjustment time prediction plate is based on a numerical model, simulates the relation between adjustment time and adjustment time evaluation indexes under different permeability and reserve abundance, and determines and establishes encryption adjustment time under different permeability and reserve abundance by using an adjustment time evaluation index standard.
7. The method for predicting the reasonable well pattern density and the time for adjusting encryption of a tight gas reservoir according to claim 6, wherein: the numerical model is established based on geological characteristic parameters of the near-interest dense sandstone gas reservoir;
and the adjustment time evaluation index is the accumulated gas increment of the sand body after the dense gas reservoir deploys the encryption well.
The adjustment opportunity evaluation index standard is established according to the development economy of the compact gas reservoir, namely the accumulated gas production increment of sand bodies after the encryption wells are deployed is larger than or equal to the lowest average single well yield of the encryption wells;
wherein the lowest average single well production = average single well combined investment ÷ (gas price-combined operating fee-unit tax);
wherein the calculation formula of the average single-well comprehensive investment is as follows:
the average single well comprehensive investment of a common well = drilling and completion cost + ground engineering construction cost;
average single well combined investment for infill wells = well completion cost.
8. A system for predicting reasonable well pattern density and encryption adjustment time of a tight gas reservoir is characterized by comprising the following steps:
the reasonable well pattern density prediction module is used for determining the reasonable well pattern density of the sand body to be predicted according to the logging permeability and the reserve abundance of the sand body to be predicted and a pre-established reasonable well pattern density prediction chart of the tight gas reservoir;
and the encryption adjusting time predicting module is used for determining the encryption adjusting time of the sand body to be predicted according to the logging permeability and the reserve abundance of the sand body to be predicted and a pre-established compact gas reservoir encryption adjusting time predicting plate.
9. A processing apparatus comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor when executing the computer program performs the steps corresponding to the tight gas reservoir reasonable pattern density and encryption adjustment timing prediction method of any one of claims 1-7.
10. A computer readable storage medium having stored thereon computer program instructions for performing the steps corresponding to the tight gas reservoir reasonable pattern density and encryption adjustment timing prediction method of any one of claims 1-7 when executed by a processor.
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| CN117967270A (en) * | 2024-02-05 | 2024-05-03 | 西南石油大学 | Low-permeability tight gas reservoir adjustment encryption well pattern deployment method |
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