Gas reservoir type CAES well selection and spacing method, product, medium and equipment

Abstract

The invention discloses a gas reservoir type CAES well selection and spacing method, a product, a medium and equipment, and relates to the technical field of CAES development and research, the method comprises the following steps: obtaining basic data of a gas reservoir type CAES seepage region, calculating a non-Darcy seepage radius of the gas reservoir type CAES seepage region, and carrying out region division; constructing productivity prediction models of the vertical well and the horizontal well by using underground seepage theories of different areas; respectively constructing pressure equations of the vertical well and the horizontal well in different areas according to the productivity prediction models of the vertical well and the horizontal well, and calculating to obtain pressure relief radiuses of the vertical well and the horizontal well; obtaining well selection and well spacing optimization functions based on the pressure relief radiuses of the vertical well and the horizontal well; and solving the well selection and well spacing optimization function to determine the most preferable well and well spacing mode, and carrying out gas reservoir type CAES construction. According to the method, the design of the gas reservoir type CAES of which the generated power meets the oil field and urban power utilization requirements can be simply and effectively realized.

Description

Technical Field

[0001] The present application relates to the technical field of CAES development and research, and in particular to a gas reservoir-type CAES well selection and well layout method, product, medium and equipment. Background Art

[0002] In recent years, the global cumulative wind power curtailment has increased seriously. In response to this situation, Compressed-Air Energy Storage (CAES) technology is often used to achieve the time-space transfer of energy, thereby smoothing the volatility of new energy. In addition, since the reconstruction of depleted gas reservoirs with CAES can reduce the electricity cost of oil and gas fields, improve production efficiency, and meet the needs of urban power supply, depleted gas reservoirs are the preferred type of storage.

[0003] In order to meet the electricity demand of oil fields and cities, depleted gas reservoir CAES requires a larger power generation capacity, and the power generation capacity under different well selection and well layout methods is also different. Therefore, it is necessary to optimize the well selection and well layout design of depleted gas reservoir CAES. At present, the existing technology still lacks the method of optimizing the well selection and well layout design of gas reservoir CAES, especially for the unknown gas well production capacity under high-speed non-Darcy seepage, which makes the existing technology unable to guarantee the electricity demand of oil fields and cities, and directly affects the efficient construction of gas reservoir CAES. Summary of the invention

[0004] The purpose of this application is to provide a gas reservoir type CAES well selection and well layout method, product, medium and equipment, which can simply and effectively realize the design of a gas reservoir type CAES whose power generation capacity meets the electricity demand of oil fields and cities.

[0005] To achieve the above objectives, this application provides the following solutions:

[0006] In a first aspect, the present application provides a gas reservoir-type CAES well selection and well layout method, comprising:

[0007] Obtain basic data of the gas reservoir type CAES seepage area; the basic data include: standard state pressure, air molar mass, gas relative density, standard state temperature, gas universal constant, gas production, gas reservoir thickness, porosity, reservoir original permeability, stress sensitivity coefficient, original formation pressure, slip effect coefficient, average formation pressure, standard state gas compressibility coefficient, gas compressibility coefficient, standard state gas density, gas density, gas viscosity, average gas viscosity, reservoir temperature, formation far pressure, wellbore pressure, formation far half radius and wellbore radius;

[0008] The non-Darcy seepage radius of the seepage area of ​​gas reservoir-type CAES is calculated based on basic data;

[0009] According to the non-Darcy seepage radius, the seepage area of ​​gas reservoir-type CAES is divided into Darcy seepage area and non-Darcy seepage area.

[0010] Based on the non-Darcy seepage radius and basic data, the production capacity prediction model of vertical wells and horizontal wells was constructed using the underground seepage theory of different regions;

[0011] According to the productivity prediction models of vertical wells and horizontal wells, the pressure equations of vertical wells and horizontal wells in different areas are constructed respectively;

[0012] The pressure relief radius of vertical wells and horizontal wells is calculated by using the pressure equations of vertical wells and horizontal wells in different zones;

[0013] Based on the pressure relief radius of vertical wells and horizontal wells, the optimization function of well selection and well layout is obtained;

[0014] Solve the optimization function of well selection and well layout to determine the best well selection and well layout method, and then carry out the construction of gas reservoir type CAES.

[0015] Optionally, the non-Darcy seepage radius of the gas reservoir-type CAES seepage area is calculated based on basic data, specifically including:

[0016] Based on the basic data, the formula Calculate the non-Darcy seepage radius r of the seepage area of ​​gas reservoir-type CAES hv ; Among them, p sc is the standard pressure; m air is the molar mass of air; γ g is the relative density of gas; T sc is the standard state temperature; R is the universal gas constant; q sc is the gas production; h is the thickness of the gas reservoir; Re is the Reynolds number; is the porosity; k i is the original permeability of the reservoir; α is the stress sensitivity coefficient; p i is the original formation pressure; b is the slip effect coefficient; is the average formation pressure; μ is the gas viscosity.

[0017] Optionally, the gas reservoir-type CAES seepage area is divided into a Darcy seepage area and a non-Darcy seepage area according to the non-Darcy seepage radius, specifically including:

[0018] When the seepage radius is larger than the non-Darcy seepage radius r hv When the fluid seepage obeys Darcy seepage and belongs to the Darcy seepage zone; when the seepage radius is smaller than the non-Darcy seepage radius r hv When , the fluid seepage obeys non-Darcy seepage and belongs to the non-Darcy seepage zone.

[0019] Optionally, the production capacity prediction model of vertical wells and horizontal wells is constructed based on the non-Darcy seepage radius and basic data using underground seepage theory in different zones, specifically including:

[0020] Based on the non-Darcy seepage radius r hv , using the underground seepage theory of different zones to construct a vertical well production capacity prediction model: in, is the pseudo pressure at the far end of the formation; is the pseudo pressure at the formation wellbore; T is the reservoir temperature; Z sc is the gas compression coefficient under standard conditions; β is the inertia coefficient; r w is the wellbore radius; r e is the far radius of the formation; is the average gas viscosity; ρ gsc is the gas density under standard conditions;

[0021] Based on the non-Darcy seepage radius r hv , using the underground seepage theory of different zones to construct a horizontal well productivity prediction model: Where c is the half length of the horizontal well;

[0022] Optionally, the pressure equations of vertical wells and horizontal wells in different zones are constructed respectively according to the productivity prediction models of vertical wells and horizontal wells, specifically including:

[0023] According to the vertical well production capacity prediction model, the pressure equation of the vertical well in the Darcy seepage zone is constructed as follows:

[0024] According to the vertical well production capacity prediction model, the pressure equation of the vertical well in the non-Darcy seepage zone is constructed as follows:

[0025] According to the horizontal well production capacity prediction model, the pressure equation of the horizontal well in the Darcy seepage zone is constructed as follows:

[0026] According to the horizontal well production capacity prediction model, the pressure equation of the horizontal well in the non-Darcy seepage zone is constructed as follows: Where r is the distance between the position to be measured and the center of the well; m * is the pseudo pressure at the position to be measured;

[0027] Optionally, the pressure relief radius of the vertical well and the horizontal well is calculated by using the pressure equations of the vertical well and the horizontal well in different zones, specifically including:

[0028] Combine the pressure equations of vertical wells and horizontal wells in different areas to calculate the pseudo-pressure m at the measured position * ;

[0029] According to the pseudo pressure m at each position to be measured * Obtain the pressure value p at each position to be measured;

[0030] when When r is used as the pressure relief radius, the pressure relief radius r of the vertical well is obtained. 1 and the pressure relief radius r of the horizontal well 2 ; Among them, ε is the preset coefficient.

[0031] Optionally, the well selection and well layout optimization function is obtained based on the pressure relief radius of the vertical well and the horizontal well, specifically including:

[0032] Pressure relief radius r based on vertical well 1 and the pressure relief radius r of the horizontal well 2 Get the well selection and well layout optimization function Among them, CO = MC 1 +NC 2 , M is the number of vertical wells; N is the number of horizontal wells; C 1 is the cost of each vertical well; C 2 is the cost of each horizontal well; P is the power generation power, which is obtained by the production capacity prediction model.

[0033] In a second aspect, the present application provides a computer program product, including a computer program, which, when executed by a processor, implements the gas reservoir-type CAES well selection and well layout method.

[0034] In a third aspect, the present application provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the gas reservoir-type CAES well selection and well layout method.

[0035] In a fourth aspect, the present application provides a computer device, comprising: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the gas reservoir-type CAES well selection and layout method.

[0036] According to the specific embodiments provided in this application, this application discloses the following technical effects:

[0037] The present application provides a gas reservoir type CAES well selection and well layout method, product, medium and equipment, first predicts the production capacity that affects the well selection, divides the gas reservoir type CAES seepage area into Darcy seepage area and non-Darcy seepage area according to the non-Darcy seepage radius, uses the nonlinear underground seepage theory of high-speed non-Darcy flow, and establishes a production capacity prediction model for vertical wells and horizontal wells that considers the non-Darcy radius through the underground seepage theory to predict the production capacity. Then, according to the production capacity prediction model, the pressure equations of vertical wells and horizontal wells in different areas are constructed, the distribution of formation pressure is determined, and according to the distribution of formation pressure, a pressure relief radius calculation model that affects well selection and gas relief area is established through mathematical modeling, and the pressure relief radius of vertical wells and horizontal wells is calculated. Finally, based on the pressure relief radius of vertical wells and horizontal wells, a well selection and well layout optimization function is established according to the factors that need to be comprehensively considered when selecting and arranging wells for gas reservoir type energy storage, which has a certain guiding role in the efficient construction of gas reservoir type CAES. The application process of the present application is simple and reliable, and can optimize the design of well selection and well layout for gas reservoir-type CAES under high-frequency injection and production under different conditions. It only needs to adjust the geological parameters. Therefore, the present application has good reliability, that is, the present application can simply and effectively realize the design of gas reservoir-type CAES whose power generation capacity meets the electricity demand of oil fields and cities. BRIEF DESCRIPTION OF THE DRAWINGS

[0038] In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the drawings required for use in the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative work.

[0039] Figure 1 A schematic diagram of the process of the gas reservoir-type CAES well selection and well layout method provided in this application;

[0040] Figure 2 A schematic diagram of the pressure distribution curve when there is no interference between the two wells provided for this application;

[0041] Figure 3 A distribution map of gas wells in the gas reservoir provided for this application;

[0042] Figure 4 Well selection and well layout optimization flow chart provided for this application;

[0043] Figure 5 Schematic diagram of the change of non-Darcy seepage radius of a vertical well with production pressure difference provided for this application;

[0044] Figure 6 A schematic diagram showing the variation of the non-Darcy seepage radius of a horizontal well with the production pressure difference provided in this application;

[0045] Figure 7 A schematic diagram comparing the field production data of vertical wells and horizontal wells provided in this application with the capacity prediction model data;

[0046] Figure 8 Pressure distribution map of non-Darcy seepage zone of vertical well provided for this application;

[0047] Fig. 9 Pressure distribution map of Darcy seepage zone of vertical well provided for this application;

[0048] Fig.10 Pressure distribution map of non-Darcy seepage zone of horizontal well provided for this application;

[0049] Fig.11 Pressure distribution map of Darcy seepage zone of horizontal well provided for this application;

[0050] Fig.12 A relationship diagram between the well selection and well layout optimization function and the number of horizontal wells provided in this application. DETAILED DESCRIPTION

[0051] The following will be combined with the drawings in the embodiments of the present application to clearly and completely describe the technical solutions in the embodiments of the present application. Obviously, the described embodiments are only part of the embodiments of the present application, not all of the embodiments. Based on the embodiments in the present application, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of this application.

[0052] In order to make the above-mentioned objects, features and advantages of the present application more obvious and easy to understand, the present application is further described in detail below in conjunction with the accompanying drawings and specific implementation methods.

[0053] like Figure 1 As shown, a gas reservoir-type CAES well selection and well layout method disclosed in the present application includes:

[0054] Step 1: Obtain basic data of the gas reservoir-type CAES seepage area.

[0055] After determining the gas reservoir-type CAES seepage area, it is necessary to obtain basic data such as the standard state pressure, air molar mass, gas relative density, standard state temperature, gas universal constant, gas production, gas reservoir thickness, porosity, reservoir original permeability, stress sensitivity coefficient, original formation pressure, slip effect coefficient and average formation pressure in this area.

[0056] Step 2: Calculate the non-Darcy seepage radius of the gas reservoir-type CAES seepage area based on the basic data.

[0057] First, the depleted gas reservoir CAES seepage area needs to be divided into Darcy seepage area and non-Darcy seepage area. The two areas are defined by the non-Darcy seepage radius. At the non-Darcy seepage radius, the gas density and velocity are the same as those in the Darcy seepage area. Based on this, the non-Darcy seepage radius r is obtained. hv The expression is:

[0058]

[0059] Among them, p sc is the standard pressure, MPa; M air is the molar mass of air, 28.96 g / mol; γ g is the relative density of gas; T sc is the standard state temperature, K; R is the universal gas constant, 8.314 J / (mol·K); q sc is the gas production (capacity), m 3 / s; h is the thickness of the gas reservoir, m; Re is the Reynolds number; is the porosity; k i is the original permeability of the reservoir, ×10 -3 μm 2 ; α is the stress sensitivity coefficient, MPa -1 ;p i is the original formation pressure, MPa; b is the slip effect coefficient, MPa; is the average formation pressure, MPa; μ is the gas viscosity, mPa·s.

[0060] Step 3: Divide the gas reservoir-type CAES seepage area into Darcy seepage area and non-Darcy seepage area according to the non-Darcy seepage radius.

[0061] Calculate the non-Darcy seepage radius r hv After that, when the seepage radius is larger than the non-Darcy seepage radius r hv When the fluid seepage obeys Darcy seepage and belongs to the Darcy seepage zone; when the seepage radius is smaller than the non-Darcy seepage radius r hv When , the fluid seepage obeys non-Darcy seepage and belongs to the non-Darcy seepage zone.

[0062] Step 4: Based on the non-Darcy seepage radius, the production capacity prediction model of vertical wells and horizontal wells is constructed using the underground seepage theory of different zones.

[0063] The underground seepage theory in different seepage areas is different. For vertical wells, the underground seepage theory in non-Darcy seepage areas can be obtained:

[0064]

[0065] According to the underground seepage theory of Darcy seepage zone, it can be obtained that:

[0066]

[0067] According to the principle of equal pressure and flow at the intersection of cross sections, the vertical well productivity prediction model can be derived by combining formulas (2) and (3):

[0068]

[0069] in, is the pseudo pressure at the non-Darcy seepage radius; is the pseudo pressure at the far end of the formation; is the pseudo pressure at the formation wellbore; T is the reservoir temperature, K; Z sc is the gas compression coefficient under standard conditions; β is the inertia coefficient, 1 / m, r w is the wellbore radius, m; r e is the far radius of the formation, m; is the average gas viscosity, mPa·s; ρ gsc is the gas density under standard conditions.

[0070] Similarly, for horizontal wells, the underground seepage theory of non-Darcy seepage zone can be obtained:

[0071]

[0072] According to the underground seepage theory of Darcy seepage zone, it can be obtained that:

[0073]

[0074] According to the equal pressure and flow rate at the junction, the horizontal well productivity prediction model can be derived by combining formulas (5) and (6):

[0075]

[0076] Where c is the half length of the horizontal well;

[0077] Step 5: Based on the productivity prediction models of vertical wells and horizontal wells, pressure equations of vertical wells and horizontal wells in different areas are constructed respectively.

[0078] According to the vertical well productivity prediction model, a boundary at a distance r from the well center in the Darcy seepage zone is obtained. The pressure equation of the vertical well in the Darcy seepage zone is:

[0079]

[0080] At a certain boundary of the non-Darcy seepage zone at a distance r from the well center, the pressure equation of the vertical well in the non-Darcy seepage zone is:

[0081]

[0082] According to the horizontal well productivity prediction model, a boundary at a distance r from the well center in the Darcy seepage zone is obtained. The pressure equation of the horizontal well in the Darcy seepage zone is:

[0083]

[0084] At a certain boundary of the non-Darcy seepage zone at a distance r from the well center, the pressure equation of the horizontal well in the non-Darcy seepage zone is:

[0085]

[0086] Where r is the distance between the position to be measured and the center of the well; m * is the pseudo pressure at the position to be measured;

[0087] Step 6: Calculate the pressure relief radius of the vertical well and horizontal well through the pressure equations of the vertical well and horizontal well in different areas.

[0088] According to formulas (8)-(11) in step 5, the distribution of formation pressure in vertical wells and horizontal wells can be determined. According to the pressure drop superposition criterion, when a well has no effect on the pressure drop change of other wells, it can be considered that there is no interference between wells. When , the pressure drop at this point can be considered to be 0, and this point has no effect on the pressure drop changes of other wells, where the preset coefficient ε is determined by different gas reservoirs. Figure 2 As shown, at this time, well 1 and well 2 have no interference phenomenon between wells, so the pressure relief radius satisfies The formation pressure distribution can be determined And then determine the pressure relief radius.

[0089] Specifically, the pseudo-pressure m at the position to be measured is calculated by combining the pressure equations of the vertical well and the horizontal well in different zones through formulas (8)-(11) in step 5: * ; According to the pseudo pressure m at each position to be measured * Get the pressure value p at each position to be measured; when When r is used as the pressure relief radius, the pressure relief radius r of the vertical well is obtained. 1 and the pressure relief radius r of the horizontal well 2 .

[0090] Step 7: Obtain the well selection and well layout optimization function based on the pressure relief radius of the vertical well and the horizontal well.

[0091] If there is interference between wells, the productivity of each well will be reduced, making the overall optimization function smaller. In order to maximize the optimization function, the well spacing should be equal to the sum of the gas leakage radius between the wells, that is, the control range of each well should be closely arranged. Assume that the closed area of ​​a gas reservoir is S0 , M vertical wells, N horizontal wells, closely arranged as follows Figure 3 As shown in the figure, since there must be a dead gas zone when the circular control range is arranged, the actual area occupied by each well is approximately the area of ​​a square with a side length of twice the pressure relief radius. Therefore, under this condition, the relationship between the vertical well and the horizontal well is:

[0092]

[0093] When selecting and arranging wells for CAES, not only the total amount of electric energy conversion should be considered, but also the economic benefits and gas leakage area. Therefore, the well selection and well arrangement optimization function is defined as follows:

[0094]

[0095] Where F is the well selection and well layout optimization function, MW / (￥·m 2 ); CO is the total cost of well layout, ￥; S is the total gas leakage area of ​​well layout, m 2 .

[0096] The expressions of CO and S are:

[0097] CO=MC 1 +NC 2 (14)

[0098]

[0099] Where, M and N are the number of vertical wells and horizontal wells respectively; C 1 , C 2 are the costs of each vertical well and horizontal well, ￥; r 1 、r 2 are the pressure relief radius of vertical well and horizontal well respectively, m; P is the power generation power.

[0100] The relationship between air mass flow and power generation is:

[0101] P=λq m (16)

[0102] Where P is the power generation, MW; λ is the proportionality coefficient, q m is the air mass flow rate, kg / s, q m By q sc To obtain.

[0103] Step 8: Solve the well selection and well layout optimization function to determine the best well selection and well layout method, and then carry out gas reservoir-type CAES construction.

[0104] Solve the optimization function of well selection and well layout. The larger the value of the optimization function, the more optimized the well selection and well layout method is. The optimal well selection and well layout method is determined accordingly.

[0105] like Figure 4 As shown, the specific steps are as follows:

[0106] ① Set the number of horizontal wells N and the maximum optimization function F max , the number of horizontal wells N that meet the maximum optimization coefficient max , the initial values ​​are all 0.

[0107] ② Calculate the number of vertical wells M according to formula (12) so that the gas wells can be arranged to the maximum extent possible without interfering with each other.

[0108] ③ Determine the size of M. If M<0, it means that the number of horizontal wells has exceeded the maximum number of horizontal wells that can be arranged without interfering with each other. Output F max 、N max ; If M ≥ 0, calculate the total power generation power P, the total cost of well layout CO, the total gas leakage area of ​​well layout S, and the optimization function F.

[0109] ④Judge F and F max If f>F max , then F max =F,N max =N, that is, replace the maximum optimization coefficient and the number of horizontal wells that meet the maximum optimization coefficient; if F≤F max , or the maximum optimization coefficient and the number of horizontal wells that meet the maximum optimization coefficient have been replaced, N = N + 1, return to step ② and recalculate, that is, calculate the optimization function when there is one more horizontal well.

[0110] According to the above process, the number of vertical wells and horizontal wells that meet the maximum optimization function are calculated.

[0111] As a specific embodiment, this application selects the depleted gas reservoir in the Mabei 8 block, and the basic parameters are shown in the following table:

[0112] Table 1 Basic parameters of depleted gas reservoirs

[0113]

[0114] Table 2 Basic parameters of compressed air

[0115]

[0116] Table 3 Basic parameters of production gas wells

[0117] name symbol size Wellbore radius <![CDATA[r w ]]> 0.1m Horizontal well half length c 150m

[0118] The variation of non-Darcy flow radius of vertical well and horizontal well with production pressure difference is shown as follows: Figure 5 and Figure 6It can be seen that when the production pressure difference is 1MPa, the non-Darcy seepage radius of the vertical well is 28.4m, and the non-Darcy seepage radius of the horizontal well is 43.3m.

[0119] like Figure 7 As shown, the field production data of vertical wells and horizontal wells are 180,000 cubic meters per day and 270,000 cubic meters per day respectively. The production capacities predicted by the production capacity prediction model are 178,740 cubic meters per day and 266,168 cubic meters per day respectively. The simulation between the field production data and the production capacity model prediction data is very good, which proves the correctness of the production capacity prediction model.

[0120] like Figure 8 and Fig. 9 As shown in Figure 1, the pressure distribution in the non-Darcy seepage zone and the pressure distribution in the Darcy seepage zone of the vertical well are obtained based on the non-Darcy seepage radius.

[0121] like Fig.10 and Fig.11 As shown in Figure 1, the pressure distribution in the non-Darcy seepage zone and the pressure distribution in the Darcy seepage zone of the horizontal well are obtained based on the non-Darcy seepage radius.

[0122] According to the calculation model of the pressure relief radius, the gas reservoir ε=10 -6 , calculate the vertical well pressure relief radius r 1 About 475m, flat well pressure relief radius r 2 It is about 711m.

[0123] The power generation capacity calculated from the relationship between air mass flow rate and power generation and the capacity model is obtained, and the power generation capacity of a single vertical well and a single horizontal well is 224.7MW and 334.6MW respectively.

[0124] The relationship between the number of horizontal wells N and the number of vertical wells M in the gas reservoir is shown in Table 4:

[0125] Table 4 Relationship between the number of horizontal wells N and the number of vertical wells M

[0126] N M 0 27 1 25 2 23 3 20 4 18 5 16 6 14 7 12 8 9 9 7 10 5 11 3 12 0

[0127] The cost of a single vertical well and a single horizontal well is 1￥ and 1.5￥ respectively, so the optimization function is:

[0128]

[0129] The curve of the optimization function changing with the number of horizontal wells N is obtained as follows: Fig.12As shown in the figure, the curve is distributed in a wavy line. The maximum number of horizontal wells that meet the principle of maximizing the optimization function is 12. When the number of horizontal wells is 0-2, 3-7, and 8-11, the well selection and well layout optimization function decreases with the increase of the number of horizontal wells. When the number of horizontal wells is 2-3, 7-8, and 11-12, the well selection and well layout optimization function increases with the increase of the number of horizontal wells. When there are 3 horizontal wells, the well selection and well layout optimization function is the largest, which is 1.184×10 -5 MW / (￥·m 2 ), according to Table 4, when there are 3 horizontal wells, there are 20 vertical wells. Therefore, when there are 3 horizontal wells and 20 vertical wells, the well selection and well layout method is optimal.

[0130] In summary, this application has established a well selection and well layout optimization function based on the factors that need to be comprehensively considered when selecting and arranging wells for gas reservoir-type energy storage, which has a certain guiding role in the efficient construction of gas reservoir-type CAES. The application process of this application is simple and reliable, and can optimize the design of well selection and well layout for gas reservoir-type CAES under high-frequency injection and production under different conditions. It only needs to adjust the geological parameters. Therefore, this application has good reliability, that is, this application can simply and effectively realize the design of gas reservoir-type CAES whose power generation capacity meets the electricity demand of oil fields and cities, and provide guarantee for the efficient construction and safe operation of gas reservoir-type CAES.

[0131] In some embodiments, the present invention further provides a computer program product, including a computer program, which, when executed by a processor, implements the gas reservoir-type CAES well selection and well layout method.

[0132] In some embodiments, the present invention further provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the gas reservoir-type CAES well selection and well layout method.

[0133] In some embodiments, the present invention also provides a computer device, including a processor, a memory, an input / output interface (I / O for short), a communication interface, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the gas reservoir-type CAES well selection and layout method.

[0134] Wherein, the processor, memory and input / output interface are connected through a system bus, and the communication interface is connected to the system bus through the input / output interface. Wherein, the processor of the computer device is used to provide computing and control capabilities. The memory of the computer device includes a non-volatile storage medium and an internal memory. The non-volatile storage medium stores an operating system, a computer program and a database. The internal memory provides an environment for the operation of the operating system and the computer program in the non-volatile storage medium. The database of the computer device is used to store pending transactions. The input / output interface of the computer device is used to exchange information between the processor and an external device. The communication interface of the computer device is used to communicate with an external terminal through a network connection. When the computer program is executed by the processor, the gas reservoir-type CAES well selection and well layout method is implemented.

[0135] It should be noted that the object information (including but not limited to object device information, object personal information, etc.) and data (including but not limited to data used for analysis, stored data, displayed data, etc.) involved in the present invention are all information and data authorized by the object or fully authorized by all parties, and the collection, use and processing of relevant data need to comply with relevant laws, regulations and standards of relevant countries and regions.

[0136] Those skilled in the art can understand that all or part of the processes in the above-mentioned embodiments can be completed by instructing the relevant hardware through a computer program, and the computer program can be stored in a non-volatile computer-readable storage medium. When the computer program is executed, it can include the processes of the embodiments of the above-mentioned methods. Among them, any reference to the memory, database or other medium used in the embodiments provided by the present invention can include at least one of non-volatile and volatile memory. Non-volatile memory can include read-only memory (ReadOnlyMemory, ROM), magnetic tape, floppy disk, flash memory, optical memory, high-density embedded non-volatile memory, resistive random access memory (ReRAM), magnetic random access memory (MRAM), ferroelectric random access memory (FRAM), phase change memory (PCM), graphene memory, etc. Volatile memory can include random access memory (RAM) or external cache memory, etc. As an illustration and not limitation, RAM can be in various forms, such as static random access memory (SRAM) or dynamic random access memory (DRAM). The database involved in each embodiment provided by the present invention may include at least one of a relational database and a non-relational database. Non-relational databases may include distributed databases based on blockchains, etc., but are not limited thereto. The processor involved in each embodiment provided by the present invention may be a general-purpose processor, a central processing unit, a graphics processor, a digital signal processor, a programmable logic device, a data processing logic device based on quantum computing, etc., but are not limited thereto.

[0137] The technical features of the above embodiments may be combined arbitrarily. To make the description concise, not all possible combinations of the technical features in the above embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of this specification.

[0138] This article uses specific examples to illustrate the principles and implementation methods of this application. The description of the above embodiments is only used to help understand the method and core ideas of this application. At the same time, for those skilled in the art, according to the ideas of this application, there will be changes in the specific implementation methods and application scope. In summary, the content of this specification should not be understood as limiting this application.

Claims

1. A gas reservoir type CAES well selection and well layout method, characterized in that: include: Obtain basic data of gas reservoir-type CAES seepage area; The basic data include: standard state pressure, air molar mass, gas relative density, standard state temperature, gas universal constant, gas production, gas reservoir thickness, porosity, reservoir original permeability, stress sensitivity coefficient, original formation pressure, slip effect coefficient, average formation pressure, standard state gas compressibility coefficient, gas compressibility coefficient, standard state gas density, gas density, gas viscosity, average gas viscosity, reservoir temperature, formation remote pressure, wellbore pressure, formation remote semi-radius and wellbore radius; The non-Darcy seepage radius of the seepage area of ​​gas reservoir-type CAES is calculated based on basic data; According to the non-Darcy seepage radius, the seepage area of ​​gas reservoir-type CAES is divided into Darcy seepage area and non-Darcy seepage area. Based on the non-Darcy seepage radius and basic data, the production capacity prediction model of vertical wells and horizontal wells was constructed using the underground seepage theory of different regions; According to the productivity prediction models of vertical wells and horizontal wells, the pressure equations of vertical wells and horizontal wells in different areas are constructed respectively; The pressure relief radius of vertical wells and horizontal wells is calculated by using the pressure equations of vertical wells and horizontal wells in different zones; Based on the pressure relief radius of vertical wells and horizontal wells, the optimization function of well selection and well layout is obtained; Solve the optimization function of well selection and well layout to determine the best well selection and well layout method, and then carry out the construction of gas reservoir type CAES.

2. The gas reservoir type CAES well selection and well layout method according to claim 1, characterized in that: The non-Darcy seepage radius of the gas reservoir-type CAES seepage area is calculated based on the basic data, specifically including: Based on the basic data, the formula Calculate the non-Darcy seepage radius r of the seepage area of ​​gas reservoir-type CAES hv ; Among them, p sc is the standard pressure; M air is the molar mass of air; γ g is the relative density of gas; T sc is the standard state temperature; R is the universal gas constant; q sc is the gas production; h is the thickness of the gas reservoir; Re is the Reynolds number; is the porosity; k i is the original permeability of the reservoir; α is the stress sensitivity coefficient; p i is the original formation pressure; b is the slip effect coefficient; is the average formation pressure; μ is the gas viscosity.

3. The gas reservoir type CAES well selection and well layout method according to claim 2, characterized in that: The gas reservoir type CAES seepage area is divided into a Darcy seepage area and a non-Darcy seepage area according to the non-Darcy seepage radius, specifically including: When the seepage radius is larger than the non-Darcy seepage radius r hv When the fluid seepage obeys Darcy seepage and belongs to the Darcy seepage zone; when the seepage radius is smaller than the non-Darcy seepage radius r hv When , the fluid seepage obeys non-Darcy seepage and belongs to the non-Darcy seepage zone.

4. The gas reservoir type CAES well selection and well layout method according to claim 2, characterized in that: Based on the non-Darcy seepage radius and basic data, the production capacity prediction model of vertical wells and horizontal wells is constructed by using the underground seepage theory of different regions, which specifically includes: Based on the non-Darcy seepage radius r hv , using the underground seepage theory of different zones to construct a vertical well production capacity prediction model: in, is the pseudo pressure at the far end of the formation; is the pseudo pressure at the formation wellbore; T is the reservoir temperature; Z sc is the gas compression coefficient under standard conditions; β is the inertia coefficient; r w is the wellbore radius; r e is the far radius of the formation; is the average gas viscosity; ρ gsc is the gas density under standard conditions; Based on the non-Darcy seepage radius r hv , using the underground seepage theory of different zones to construct a horizontal well productivity prediction model: Where c is the half length of the horizontal well; 5. The gas reservoir type CAES well selection and well layout method according to claim 4, characterized in that: The pressure equations of vertical wells and horizontal wells in different zones are constructed according to the productivity prediction models of vertical wells and horizontal wells, specifically including: According to the vertical well production capacity prediction model, the pressure equation of the vertical well in the Darcy seepage zone is constructed as follows: According to the vertical well production capacity prediction model, the pressure equation of the vertical well in the non-Darcy seepage zone is constructed as follows: According to the horizontal well production capacity prediction model, the pressure equation of the horizontal well in the Darcy seepage zone is constructed as follows: According to the horizontal well production capacity prediction model, the pressure equation of the horizontal well in the non-Darcy seepage zone is constructed as follows: Where r is the distance between the position to be measured and the center of the well; m * is the pseudo pressure at the position to be measured; 6. The gas reservoir type CAES well selection and well layout method according to claim 5, characterized in that: The pressure relief radius of the vertical well and the horizontal well is calculated by the pressure equations of the vertical well and the horizontal well in different zones, specifically including: Combine the pressure equations of vertical wells and horizontal wells in different areas to calculate the pseudo-pressure m at the measured position * ; According to the pseudo pressure m at each position to be measured * Obtain the pressure value p at each position to be measured; when When , r at this time is used as the pressure relief radius to obtain the pressure relief radius r1 of the vertical well and the pressure relief radius r2 of the horizontal well; where ε is the preset coefficient.

7. The gas reservoir type CAES well selection and well layout method according to claim 6, characterized in that: The well selection and well layout optimization function is obtained based on the pressure relief radius of the vertical well and the horizontal well, specifically including: Based on the pressure relief radius r1 of the vertical well and the pressure relief radius r2 of the horizontal well, the optimization function of well selection and well layout is obtained. Among them, CO = MC1 + NC2, M is the number of vertical wells; N is the number of horizontal wells; C1 is the cost of each vertical well; C2 is the cost of each horizontal well; P is the power generation, which is obtained by the capacity prediction model.

8. A computer program product, comprising a computer program, characterized in that When the computer program is executed by a processor, the gas reservoir-type CAES well selection and well layout method described in any one of claims 1 to 7 is implemented.

9. A computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the gas reservoir-type CAES well selection and well layout method described in any one of claims 1 to 7 is implemented.

10. A computer device comprising: A memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the gas reservoir-type CAES well selection and layout method according to any one of claims 1 to 7.

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