Method and device for determining the number of gas production wells in the gas production stage of an underground gas storage

Abstract

The application relates to the technical field of gas storage management and control, and provides a method and device for determining the number of gas production wells in the gas production stage of an underground gas storage, which comprises the following steps: constructing the corresponding relationship between the average formation pressure and the reasonable gas production amount under different pipe diameters according to the gas production inflow dynamic curve and the gas production outflow dynamic curve; determining the corresponding relationship between the average formation pressure and the cumulative gas production amount; determining the average formation pressure according to the planned gas production time, the gas production amount per unit time, the average formation pressure and the corresponding relationship between the average formation pressure and the cumulative gas production amount, and determining the reasonable gas production amount according to the average formation pressure and the corresponding relationship between the average formation pressure and the reasonable gas production amount; and determining the number of gas production wells according to the reasonable gas production amount and the working gas amount. The method can guarantee that the peak regulation function of the gas storage is maximally exerted and provide guidance for planning the gas production work system in the gas production stage.

Description

Technical Field

[0001] This invention relates to the field of gas storage management technology, and in particular to a method and apparatus for determining the number of gas production wells during the gas production stage of an underground gas storage facility. Background Technology

[0002] A gas storage facility is a container for storing natural gas. The term "Underground Gas Storage" (UGS) generally refers to an underground gas storage facility. Underground gas storage facilities are artificial gas fields or reservoirs formed by re-injecting commercial natural gas transported through long-distance pipelines into underground spaces.

[0003] Underground gas storage facilities play a crucial role in peak energy regulation, serving as vital energy reserve facilities to ensure national gas supply security. Determining the optimal number of gas wells per production stage can fully leverage the peak-regulating capacity of gas storage facilities; however, identifying this optimal number of wells currently presents challenges. Summary of the Invention

[0004] To address the problems existing in the prior art, this invention provides a method, apparatus, electronic equipment, and storage medium for determining the number of gas production wells during the gas production stage of an underground gas storage facility.

[0005] In a first aspect, the present invention provides a method for determining the number of gas production wells during the gas production stage of an underground gas storage facility, wherein:

[0006] Obtain historical gas production capacity data of gas wells, and plot dynamic curves of gas inflow under different formation pressures based on the historical gas production capacity data.

[0007] Obtain historical vertical pipe flow data and basic wellbore data of the gas well; construct a vertical pipe flow model of the wellbore based on the historical vertical pipe flow data and basic wellbore data; and draw dynamic curves of gas outflow under different pipe diameters based on the vertical pipe flow model of the wellbore.

[0008] Based on the gas inflow dynamic curve and the gas outflow dynamic curve, a correspondence between the average formation pressure and the reasonable gas production rate under different pipe diameters is constructed.

[0009] Determine the relationship between mean formation pressure and cumulative gas production;

[0010] Determine the planned gas extraction time and gas extraction volume per unit time within the current cycle of the gas storage facility. Determine the average formation pressure based on the correspondence between the planned gas extraction time, gas extraction volume per unit time, average formation pressure, and cumulative gas extraction volume. Determine the reasonable gas extraction volume based on the correspondence between the average formation pressure, average formation pressure, and reasonable gas extraction volume.

[0011] Determine the working gas volume of the gas storage facility for the current cycle, and determine the number of gas production wells based on the reasonable gas production volume and the working gas volume.

[0012] In one embodiment, plotting the dynamic curves of gas inflow under different formation pressures based on the historical gas production capacity data includes:

[0013] A gas well production capacity model is constructed based on the historical gas production capacity data, and dynamic curves of gas inflow under different formation pressures are plotted based on the gas well production capacity model.

[0014] In one embodiment, determining the correspondence between average formation pressure and cumulative gas production includes:

[0015] A gas production phase material balance model is constructed for multiple cycles of injection / production operations. Based on the gas production phase material balance model, the correspondence between average formation pressure and cumulative gas production is determined.

[0016] In one embodiment, constructing the correspondence between average formation pressure and reasonable gas production rate under different pipe diameters based on the gas inflow dynamic curve and the gas outflow dynamic curve includes:

[0017] Obtain the intersection value of the gas inflow dynamic curve and the gas outflow dynamic curve;

[0018] The correlation between average formation pressure and reasonable gas production rate under different pipe diameters is obtained by fitting the intersection point values.

[0019] In one embodiment, the gas well production capacity model includes:

[0020]

[0021] Where, p e Formation pressure; p wf q represents the bottom hole flowing pressure; q represents the gas production rate of the gas well; and a and b are coefficients.

[0022] In one embodiment, the vertical pipe flow model of the wellbore includes:

[0023]

[0024]

[0025] Where, p tf γ is the wellhead pressure; f is the friction coefficient of the pipeline inside the well; T is the average temperature inside the well; Z is the average deviation coefficient inside the wellbore; q is the gas production rate of the gas well; D is the inner diameter of the pipe inside the well; g H represents the relative density of natural gas; H represents the depth of the middle section of the gas storage facility.

[0026] In one embodiment, the gas extraction phase material balance model includes:

[0027]

[0028] Among them, G i B represents the initial inventory level during the gas extraction phase of the gas storage facility. gi W represents the gas volume coefficient at the initial moment of the gas extraction phase. t B represents the cumulative water production at time t during the gas extraction phase. w G is the formation water volume factor; t B represents the cumulative gas extraction volume at time t during the gas extraction phase. gt C is the gas volume coefficient at time t during the gas extraction stage; s P is the water intrusion coefficient. i P represents the formation pressure at the initial moment of the gas production stage. t This represents the formation pressure at time t during the gas extraction stage.

[0029] In one embodiment, determining the working gas volume of the gas storage facility for the current cycle includes:

[0030] Construct a movable cushion gas volume state model for the gas storage facility, and determine the movable cushion gas volume based on the movable cushion gas volume state model;

[0031] The working gas volume is determined based on the movable cushion gas volume and the initial storage capacity.

[0032] In one embodiment, the movable cushion air volume state model includes:

[0033]

[0034] Among them, G min It is the air volume of the movable cushion; p min The lower limit of pressure; Z min T is the natural gas deviation coefficient corresponding to the lower limit pressure; T is the reservoir temperature; T sc p represents the temperature under standard gas conditions. sc V represents the pressure of a gas under standard conditions. m The volume of movable gas-bearing pores in the gas storage tank.

[0035] In one embodiment, determining the number of gas production wells based on the reasonable gas production rate and the working gas production rate includes:

[0036] The reasonable gas production rate and the working gas production rate are input into the gas well number determination model to determine the number of gas wells; the gas well number determination model includes:

[0037]

[0038] Among them, G work q represents the working gas volume, t represents the planned gas extraction time, and q represents the working gas volume. g To ensure a reasonable gas extraction volume.

[0039] Secondly, the present invention provides a device for determining the number of gas production wells during the gas production stage of an underground gas storage facility, characterized in that it includes:

[0040] The first processing module is used to acquire historical gas production capacity data of gas wells and draw dynamic curves of gas inflow under different formation pressures based on the historical gas production capacity data.

[0041] The second processing module is used to acquire historical vertical pipe flow data and basic wellbore data of the gas well, construct a vertical pipe flow model of the wellbore based on the historical vertical pipe flow data and basic wellbore data, and draw dynamic curves of gas outflow under different pipe diameters based on the vertical pipe flow model of the wellbore.

[0042] The module is used to construct the correspondence between average formation pressure and reasonable gas production volume under different pipe diameters based on the gas inflow dynamic curve and the gas outflow dynamic curve.

[0043] The first determining module is used to determine the correspondence between average formation pressure and cumulative gas production.

[0044] The second determining module is used to determine the planned gas extraction time and gas extraction volume per unit time within the current cycle of the gas storage facility. It determines the average formation pressure based on the correspondence between the planned gas extraction time, gas extraction volume per unit time, average formation pressure, and cumulative gas extraction volume. It also determines the reasonable gas extraction volume based on the correspondence between the average formation pressure and the reasonable gas extraction volume.

[0045] The third determining module is used to determine the working gas volume of the gas storage facility in the current cycle, and to determine the number of gas production wells based on the reasonable gas production volume and the working gas volume.

[0046] Thirdly, the present invention provides an electronic device, including a memory and a memory storing a computer program, wherein the processor executes the program to implement the steps of the method for determining the number of gas production wells in the gas production stage of the underground gas storage facility as described in the first aspect.

[0047] Fourthly, the present invention provides a processor-readable storage medium storing a computer program for causing the processor to execute the steps of the method for determining the number of gas production wells in the gas production stage of an underground gas storage facility as described in the first aspect.

[0048] The present invention provides a method, apparatus, electronic equipment, and storage medium for determining the number of gas production wells during the gas production stage of an underground gas storage facility. It determines the relationship between average formation pressure and reasonable gas production volume through production capacity data and wellbore flow, and obtains the relationship between average formation pressure and cumulative gas production volume during the gas production stage of a multi-cycle injection-production operation of the gas storage facility. Then, based on these relationships, a reasonable gas production volume is determined, and the number of gas production wells is determined based on the current cycle's working gas volume and reasonable gas production volume. This ensures that the peak-shaving function of the gas storage facility is maximized, providing guidance for planning the gas production work system during the gas production stage. Attached Figure Description

[0049] To more clearly illustrate the technical solutions in this invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are some embodiments of this invention. For those skilled in the art, other drawings can be obtained from these drawings without creative effort.

[0050] Figure 1 This is a flowchart illustrating the method for determining the number of gas production wells during the gas production stage of an underground gas storage facility, provided by the present invention.

[0051] Figure 2 This is a schematic diagram of the inflow / outflow dynamic curve provided by the present invention;

[0052] Figure 3 This is a schematic diagram of the device for determining the number of gas production wells during the gas production stage of an underground gas storage facility provided by the present invention.

[0053] Figure 4 This is a schematic diagram of the structure of the electronic device provided by the present invention. Detailed Implementation

[0054] To make the objectives, technical solutions, and advantages of this invention clearer, the technical solutions of this invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some, not all, of the embodiments of this invention. All other embodiments obtained by those skilled in the art based on the embodiments of this invention without creative effort are within the scope of protection of this invention.

[0055] The following is combined Figures 1-4 This invention describes the method, apparatus, electronic equipment, and storage medium for determining the number of gas production wells during the gas production stage of an underground gas storage facility.

[0056] Figure 1 This diagram illustrates a method for determining the number of gas production wells during the gas production stage of an underground gas storage facility according to the present invention. (See attached diagram.) Figure 1 The method includes:

[0057] 11. Obtain historical gas production capacity data of gas wells, and plot dynamic curves of gas inflow under different formation pressures based on historical gas production capacity data;

[0058] 12. Obtain historical vertical pipe flow data and basic wellbore data of gas wells, construct a vertical pipe flow model of the wellbore based on the historical vertical pipe flow data and basic wellbore data, and draw dynamic curves of gas outflow under different pipe diameters based on the vertical pipe flow model of the wellbore.

[0059] 13. Based on the dynamic curves of gas inflow and gas outflow, construct the correspondence between the average formation pressure and the reasonable gas production rate under different pipe diameters;

[0060] 14. Determine the relationship between mean formation pressure and cumulative gas production;

[0061] 15. Determine the planned gas extraction time and gas extraction volume per unit time within the current cycle of the gas storage facility. Determine the average formation pressure based on the relationship between the planned gas extraction time, gas extraction volume per unit time, average formation pressure, and cumulative gas extraction volume. Determine the reasonable gas extraction volume based on the relationship between the average formation pressure and the reasonable gas extraction volume.

[0062] 16. Determine the working gas volume of the gas storage facility for the current cycle, and determine the number of gas production wells based on the reasonable gas production volume and working gas volume.

[0063] Regarding steps 11 to 16, it should be noted that in this invention, a gas storage facility refers to a "container" for storing natural gas. The commonly used term "Underground Gas Storage" (UGS) generally refers to an underground gas storage facility. An underground gas storage facility is an artificial gas field or reservoir formed by re-injecting commercial natural gas transported through long-distance pipelines into underground space. Therefore, a gas storage facility has an injection stage and a production stage. The injection stage involves injecting external natural gas into the gas storage facility. The production stage involves harvesting natural gas from the gas storage facility. Both injection and production require gas wells.

[0064] In this invention, during the gas production stage, historical gas production capacity data of the gas well needs to be obtained. This data may include formation pressure, bottom hole flowing pressure, and gas production volume. The historical gas production capacity data is then analyzed to fit and plot dynamic curves of gas inflow under different formation pressures.

[0065] During the gas production phase, it is also necessary to obtain historical vertical pipe flow data and basic wellbore data. The historical vertical pipe flow data may include wellhead pressure and gas production rate. The basic wellbore data includes the wellbore friction coefficient, average wellbore temperature, average wellbore deviation coefficient, wellbore pipe diameter, and the depth at the center of the gas storage tank.

[0066] A vertical flow model for the wellbore was obtained by fitting historical vertical flow data and basic wellbore data. This vertical flow model includes:

[0067]

[0068]

[0069] Where, p tf γ is the wellhead pressure; f is the friction coefficient of the pipeline inside the well; T is the average temperature inside the well; Z is the average deviation coefficient inside the wellbore; q is the gas production rate of the gas well; D is the inner diameter of the pipe inside the well; g H represents the relative density of natural gas; H represents the depth of the middle section of the gas storage facility.

[0070] Based on the vertical pipe flow model of the wellbore, dynamic curves of gas production outflow under different pipe diameters are plotted in a coordinate system with gas production volume as the abscissa and bottom hole pressure as the ordinate.

[0071] In this invention, in a coordinate system with gas production volume as the abscissa and bottom hole pressure as the ordinate, the dynamic curves of gas inflow and gas outflow can intersect. Based on these intersection points, the correspondence between the average formation pressure and the reasonable gas production volume under different pipe diameters can be obtained. This correspondence is a functional relationship.

[0072] In this invention, the gas storage facility operates on an annual cycle. During the gas extraction period, the storage facility already contains natural gas. At each cycle's injection and extraction phase, a balance needs to be maintained between the existing inventory and the cumulative extracted gas volume. Therefore, by analyzing data such as inventory levels and extracted gas volumes at different extraction times within the cycle, the correlation between average formation pressure and cumulative extracted gas volume is determined. This correlation is also a functional relationship, interrelated with the correlation between average formation pressure and reasonable extracted gas volume.

[0073] In this invention, to determine the number of gas wells currently needed for gas extraction, it is necessary to clarify the planned gas extraction time and gas extraction volume per unit time within the current cycle of the gas storage facility. The planned gas extraction time can be the planned number of gas extraction days, and the gas extraction volume per unit time can be the daily or monthly gas extraction volume. The average formation pressure is determined based on the relationship between the planned gas extraction time, the gas extraction volume per unit time, and the average formation pressure and cumulative gas extraction volume. Then, the reasonable gas extraction volume is determined based on the relationship between the average formation pressure and the reasonable gas extraction volume.

[0074] In this invention, the working gas volume of the gas storage facility for the current cycle is determined. This working gas volume is the amount of gas that can be extracted from the upper limit pressure to the lower limit pressure of the gas storage facility. Then, based on the reasonable gas extraction volume and the working gas volume, the number of gas extraction wells is determined.

[0075] The present invention provides a method for determining the number of gas production wells during the gas production stage of an underground gas storage facility. This method determines the relationship between average formation pressure and reasonable gas production volume through production capacity data and wellbore flow, and obtains the relationship between average formation pressure and cumulative gas production volume of the gas storage facility through the gas production stage of multi-cycle injection and production operation. Then, it determines the reasonable gas production volume based on these relationships, and determines the number of gas production wells based on the current cycle's working gas volume and reasonable gas production volume. This ensures that the peak-shaving function of the gas storage facility is maximized, and provides guidance for planning the gas production work system during the gas production stage.

[0076] A further method described above primarily explains the process of plotting dynamic curves of gas inflow under different formation pressures based on historical gas production capacity data, as detailed below:

[0077] A gas well production capacity model is constructed based on historical gas production capacity data, and dynamic curves of gas inflow under different formation pressures are plotted based on the gas well production capacity model.

[0078] It should be noted that the gas well production capacity model is obtained by fitting historical gas production capacity data. Furthermore, this gas well production capacity model includes:

[0079]

[0080] Where, p e Formation pressure; p wf q represents the bottom hole flowing pressure; q represents the gas production rate of the gas well; and a and b are coefficients.

[0081] Based on the gas well production capacity model, dynamic curves of gas inflow under different formation pressures are plotted in a coordinate system with gas production volume as the abscissa and bottom hole pressure as the ordinate.

[0082] The further method described above mainly explains the process of determining the correspondence between average formation pressure and cumulative gas production, as follows:

[0083] A material balance model for the gas production stage of multiple injection / production cycles is constructed, and the correspondence between mean formation pressure and cumulative gas production is determined based on the material balance model for the gas production stage.

[0084] It should be noted that in this invention, the gas-water interface extrapolation effect exists during the gas storage facility's injection / production operation. Therefore, impact data corresponding to each cycle of injection / production operation is collected, and then a material balance model for the production stage of multi-cycle injection / production operation of the gas storage facility is provided based on this data. This production stage material balance model includes:

[0085]

[0086] Among them, G iB represents the initial inventory level during the gas extraction phase of the gas storage facility. gi W represents the gas volume coefficient at the initial moment of the gas extraction phase. t B represents the cumulative water production at time t during the gas extraction phase. w G is the formation water volume factor; t B represents the cumulative gas extraction volume at time t during the gas extraction phase. gt C is the gas volume coefficient at time t during the gas extraction stage; s P is the water intrusion coefficient. i P represents the formation pressure at the initial moment of the gas production stage. t This represents the formation pressure at time t during the gas extraction stage.

[0087] Based on the material balance model of the gas production stage, the correspondence between average formation pressure and cumulative gas production is extracted.

[0088] A further step in the above method mainly explains the process of constructing the correspondence between average formation pressure and reasonable gas production rate under different pipe diameters based on the gas inflow dynamic curve and the gas outflow dynamic curve, as detailed below:

[0089] Obtain the intersection value of the gas inflow dynamic curve and the gas outflow dynamic curve;

[0090] The correlation between average formation pressure and reasonable gas production rate under different pipe diameters was obtained by fitting the intersection values.

[0091] It should be noted that in this invention, in a coordinate system with gas production rate as the abscissa and bottom hole flowing pressure as the ordinate, the dynamic curves of gas inflow and gas outflow can intersect. (See [reference needed]). Figure 2 As shown.

[0092] Curve 1 is the inflow dynamic curve under an average formation pressure of 19 MPa;

[0093] Curve 2 is the inflow dynamic curve under an average formation pressure of 21 MPa;

[0094] Curve 3 is the inflow dynamic curve under an average formation pressure of 23 MPa;

[0095] Curve 4 is the inflow dynamic curve under an average formation pressure of 25 MPa;

[0096] Curve 5 is the inflow dynamic curve under an average formation pressure of 27 MPa;

[0097] Curve 6 is the inflow dynamic curve under an average formation pressure of 29 MPa;

[0098] Curve 7 is the outflow dynamic curve with an inner diameter of 3.5 in the generating tube;

[0099] Curve 8 is the outflow dynamic curve with an inner diameter of 4.5 in the generating tube;

[0100] Curve 9 is the outflow dynamic curve with an inner diameter of 5.5 inches in the generating tube.

[0101] The relationship between average formation pressure and reasonable gas production under different pipe diameters can be obtained by fitting these intersection points.

[0102] The further method described above mainly explains the process of determining the working gas volume of the gas storage facility for the current cycle, as follows:

[0103] Construct a movable cushion gas volume state model for the gas storage facility, and determine the movable cushion gas volume based on the movable cushion gas volume state model;

[0104] The working gas volume is determined based on the movable cushion gas volume and the initial storage capacity. In this invention, the working gas volume of the gas storage tank is the difference between the initial storage volume and the movable cushion gas volume.

[0105] G work =G i -G min

[0106] Among them, G work For working gas volume, G i G represents the initial inventory level. min It refers to the air volume of the movable cushion.

[0107] It should be noted that, in this invention, the movable cushion air volume state model includes:

[0108]

[0109] Among them, G min It is the air volume of the movable cushion; p min The lower limit of pressure; Z min T is the natural gas deviation coefficient corresponding to the lower limit pressure; T is the reservoir temperature; T sc p represents the temperature under standard gas conditions. sc V represents the pressure of a gas under standard conditions. m The volume of movable gas-bearing pores in the gas storage tank.

[0110] Based on the movable cushion gas volume state model, the working gas volume can be determined according to the movable cushion gas volume and the initial storage capacity.

[0111] The further method described above mainly explains the process of determining the number of gas production wells based on reasonable gas production volume and working gas volume, as follows:

[0112] The reasonable gas production rate and working gas production rate are input into the gas well number determination model to determine the number of gas wells; the gas well number determination model includes:

[0113]

[0114] Among them, G work q represents the working gas volume, t represents the planned gas extraction time, and q represents the working gas volume. g To ensure a reasonable gas extraction volume.

[0115] This invention introduces a movable storage capacity and provides a method for defining the gas production capacity during the gas production stage. Based on the gas production capacity of the gas storage, the number of gas production wells in the gas production stage is determined to ensure that the peak-shaving function of the gas storage is maximized, and to provide guidance for planning the gas production work system during the gas production stage.

[0116] The following describes the device for determining the number of gas production wells in the gas production stage of an underground gas storage facility provided by the present invention. The device for determining the number of gas production wells in the gas production stage of an underground gas storage facility described below can be referred to in correspondence with the method for determining the number of gas production wells in the gas production stage of an underground gas storage facility described above.

[0117] Figure 3 This diagram illustrates the structure of a device for determining the number of gas production wells during the gas production stage of an underground gas storage facility, provided by the present invention. (See attached diagram.) Figure 3 The device includes a first processing module 31, a second processing module 32, a construction module 33, a first determining module 34, a second determining module 35, and a third determining module 36, wherein...

[0118] The first processing module 31 is used to acquire historical gas production capacity data of gas wells and draw dynamic curves of gas inflow under different formation pressures based on historical gas production capacity data.

[0119] The second processing module 32 is used to acquire historical vertical pipe flow data and basic wellbore data of the gas well, construct a vertical pipe flow model of the wellbore based on the historical vertical pipe flow data and basic wellbore data, and draw dynamic curves of gas outflow under different pipe diameters based on the vertical pipe flow model of the wellbore.

[0120] Module 33 is used to construct the correspondence between average formation pressure and reasonable gas production volume under different pipe diameters based on the gas inflow dynamic curve and the gas outflow dynamic curve.

[0121] The first determining module 34 is used to determine the correspondence between average formation pressure and cumulative gas production.

[0122] The second determining module 35 is used to determine the planned gas extraction time and gas extraction volume per unit time in the current cycle of the gas storage facility. It determines the average formation pressure based on the relationship between the planned gas extraction time, gas extraction volume per unit time, average formation pressure, and cumulative gas extraction volume. It also determines the reasonable gas extraction volume based on the relationship between the average formation pressure and the reasonable gas extraction volume.

[0123] The third determining module 36 is used to determine the working gas volume of the gas storage facility in the current cycle, and to determine the number of gas production wells based on the reasonable gas production volume and the working gas volume.

[0124] In a further embodiment of the above-described apparatus, the first processing module is specifically used for:

[0125] A gas well production capacity model is constructed based on the historical gas production capacity data, and dynamic curves of gas inflow under different formation pressures are plotted based on the gas well production capacity model.

[0126] In a further embodiment of the above-described apparatus, the first determining module is specifically used for:

[0127] A gas production phase material balance model is constructed for multiple cycles of injection / production operations. Based on the gas production phase material balance model, the correspondence between average formation pressure and cumulative gas production is determined.

[0128] In a further embodiment of the above apparatus, the construction module is specifically used for:

[0129] Obtain the intersection value of the gas inflow dynamic curve and the gas outflow dynamic curve;

[0130] The correlation between average formation pressure and reasonable gas production rate under different pipe diameters is obtained by fitting the intersection point values.

[0131] In a further component of the aforementioned apparatus, the gas well production capacity model includes:

[0132]

[0133] Where, p e Formation pressure; p wf q represents the bottom hole flowing pressure; q represents the gas production rate of the gas well; and a and b are coefficients.

[0134] In a further embodiment of the above-mentioned apparatus, the vertical pipe flow model in the wellbore includes:

[0135]

[0136]

[0137] Where, p tf γ is the wellhead pressure; f is the friction coefficient of the pipeline inside the well; T is the average temperature inside the well; Z is the average deviation coefficient inside the wellbore; q is the gas production rate of the gas well; D is the inner diameter of the pipe inside the well; g H represents the relative density of natural gas; H represents the depth of the middle section of the gas storage facility.

[0138] In a further embodiment of the above-mentioned apparatus, the gas extraction stage material balance model includes:

[0139]

[0140] Among them, G i B represents the initial inventory level during the gas extraction phase of the gas storage facility. gi W represents the gas volume coefficient at the initial moment of the gas extraction phase. t B represents the cumulative water production at time t during the gas extraction phase. w G is the formation water volume factor; t B represents the cumulative gas extraction volume at time t during the gas extraction phase. gt C is the gas volume coefficient at time t during the gas extraction stage; s P is the water intrusion coefficient. i P represents the formation pressure at the initial moment of the gas production stage. t This represents the formation pressure at time t during the gas extraction stage.

[0141] In a further part of the above-mentioned device, the third determining module, in the process of determining the working gas volume of the gas storage tank for the current cycle, is specifically used for:

[0142] Construct a movable cushion gas volume state model for the gas storage facility, and determine the movable cushion gas volume based on the movable cushion gas volume state model;

[0143] The working gas volume is determined based on the movable cushion gas volume and the initial storage capacity.

[0144] In a further embodiment of the above-described device, the movable cushion air volume state model includes:

[0145]

[0146] Among them, G min It is the air volume of the movable cushion; p min The lower limit of pressure; Z min T is the natural gas deviation coefficient corresponding to the lower limit pressure; T is the reservoir temperature; T sc p represents the temperature under standard gas conditions. sc V represents the pressure of a gas under standard conditions. m The volume of movable gas-bearing pores in the gas storage tank.

[0147] In a further part of the above-mentioned device, the third determining module, in the process of determining the number of gas production wells based on the reasonable gas production rate and the working gas production rate, is specifically used for:

[0148] The reasonable gas production rate and the working gas production rate are input into the gas well number determination model to determine the number of gas wells; the gas well number determination model includes:

[0149]

[0150] Among them, G work q represents the working gas volume, t represents the planned gas extraction time, and q represents the working gas volume. gTo ensure a reasonable gas extraction volume.

[0151] Since the device described in this embodiment of the invention is based on the same principle as the method described in the above embodiments, more detailed explanations will not be repeated here.

[0152] It should be noted that, in the embodiments of the present invention, the relevant functional modules can be implemented by a hardware processor.

[0153] The device for determining the number of gas production wells during the gas production stage of an underground gas storage facility provided by this invention determines the relationship between average formation pressure and reasonable gas production volume through production capacity data and wellbore flow, and obtains the relationship between average formation pressure and cumulative gas production volume of the gas storage facility through the gas production stage of multi-cycle injection and production operation. Then, it determines the reasonable gas production volume based on the relationship, and determines the number of gas production wells based on the working gas volume of the current cycle and the reasonable gas production volume, so as to ensure that the peak-shaving function of the gas storage facility is maximized and to provide guidance for planning the gas production work system during the gas production stage.

[0154] Figure 4 An example is a schematic diagram of the physical structure of an electronic device, such as... Figure 4 As shown, the electronic device may include: a processor 41, a communication interface 42, a memory 43, and a communication bus 44. The processor 41, communication interface 42, and memory 43 communicate with each other via the communication bus 44. The processor 41 can call the computer program in the memory 43 to execute the steps of the method for determining the number of gas production wells during the gas production stage of the underground gas storage facility. These steps include, for example: acquiring historical gas production capacity data of the gas wells; drawing dynamic curves of gas inflow under different formation pressures based on the historical gas production capacity data; acquiring historical vertical pipe flow data and basic wellbore data of the gas wells; constructing a vertical pipe flow model based on the historical vertical pipe flow data and basic wellbore data; drawing dynamic curves of gas outflow under different pipe diameters based on the vertical pipe flow model; and drawing dynamic curves of gas inflow and gas outflow based on the dynamic curves of gas inflow and gas outflow. The dynamic curve establishes the correlation between average formation pressure and reasonable gas production rate under different pipe diameters; determines the correlation between average formation pressure and cumulative gas production rate; determines the planned gas production time and gas production rate per unit time within the current cycle of the gas storage facility; determines the average formation pressure based on the planned gas production time, gas production rate per unit time, and the correlation between average formation pressure and cumulative gas production rate; determines the reasonable gas production rate based on the correlation between average formation pressure and reasonable gas production rate; determines the working gas volume of the gas storage facility in the current cycle; and determines the number of gas production wells based on the reasonable gas production rate and working gas volume.

[0155] Furthermore, the logical instructions in the aforementioned memory 43 can be implemented as software functional units and, when sold or used as independent products, can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of the present invention, or the part that contributes to the prior art, or a part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods described in the various embodiments of the present invention. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0156] On the other hand, the present invention also provides a computer program product, which includes a computer program stored on a non-transitory computer-readable storage medium. The computer program includes program instructions, and when the program instructions are executed by a computer, the computer is able to execute the method for determining the number of gas production wells in the gas production stage of an underground gas storage facility provided by the above methods. This method includes: acquiring historical gas production capacity data of gas wells; drawing dynamic curves of gas inflow under different formation pressures based on the historical gas production capacity data; acquiring historical vertical pipe flow data and basic wellbore data of gas wells; constructing a vertical pipe flow model of the wellbore based on the historical vertical pipe flow data and basic wellbore data; and determining the number of gas production wells in the underground gas storage facility based on the vertical pipe flow data. The straight pipe flow model is used to plot the gas outflow dynamic curves for different pipe diameters. Based on the gas inflow and outflow dynamic curves, the correlation between average formation pressure and reasonable gas production volume for different pipe diameters is constructed. The correlation between average formation pressure and cumulative gas production volume is determined. The planned gas production time and gas production volume per unit time in the current cycle of the gas storage facility are determined. The average formation pressure is determined based on the planned gas production time, gas production volume per unit time, and the correlation between average formation pressure and cumulative gas production volume. The reasonable gas production volume is determined based on the correlation between average formation pressure and reasonable gas production volume. The working gas volume of the gas storage facility in the current cycle is determined. The number of gas production wells is determined based on the reasonable gas production volume and working gas volume.

[0157] On the other hand, embodiments of this application also provide a processor-readable storage medium storing a computer program. The computer program is used to cause the processor to execute the method for determining the number of gas production wells during the gas production stage of an underground gas storage facility provided in the above embodiments. For example, it includes: acquiring historical gas production capacity data of the gas wells; drawing dynamic curves of gas inflow under different formation pressures based on the historical gas production capacity data; acquiring historical vertical pipe flow data and basic wellbore data of the gas wells; constructing a vertical pipe flow model based on the historical vertical pipe flow data and the basic wellbore data; and drawing gas production curves under different pipe diameters based on the vertical pipe flow model. Dynamic curves for outflow; construct the correspondence between average formation pressure and reasonable gas production volume under different pipe diameters based on the dynamic curves for gas inflow and outflow; determine the correspondence between average formation pressure and cumulative gas production volume; determine the planned gas production time and gas production volume per unit time in the current cycle of the gas storage facility; determine the average formation pressure based on the planned gas production time, gas production volume per unit time, and the correspondence between average formation pressure and cumulative gas production volume; determine the reasonable gas production volume based on the correspondence between average formation pressure and average formation pressure and reasonable gas production volume; determine the working gas volume of the gas storage facility in the current cycle; determine the number of gas production wells based on the reasonable gas production volume and working gas volume.

[0158] The processor-readable storage medium can be any available medium or data storage device that the processor can access, including but not limited to magnetic memory (e.g., floppy disk, hard disk, magnetic tape, magneto-optical disk (MO)), optical memory (e.g., CD, DVD, BD, HVD), and semiconductor memory (e.g., ROM, EPROM, EEPROM, non-volatile memory (NAND FLASH), solid-state drive (SSD)).

[0159] The device embodiments described above are merely illustrative. The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the modules can be selected to achieve the purpose of this embodiment according to actual needs. Those skilled in the art can understand and implement this without any creative effort.

[0160] Through the above description of the embodiments, those skilled in the art can clearly understand that each embodiment can be implemented by means of software plus necessary general-purpose hardware platforms, and of course, it can also be implemented by hardware. Based on this understanding, the above technical solutions, in essence or the part that contributes to the prior art, can be embodied in the form of a software product. This computer software product can be stored in a computer-readable storage medium, such as ROM / RAM, magnetic disk, optical disk, etc., and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute the methods described in the various embodiments or some parts of the embodiments.

[0161] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, and not to limit them; although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features; and these modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A method for determining the number of gas production wells during the gas production stage of an underground gas storage facility, characterized in that, include: Obtain historical gas production capacity data of gas wells, and plot dynamic curves of gas inflow under different formation pressures based on the historical gas production capacity data. Obtain historical vertical pipe flow data and basic wellbore data of the gas well; construct a vertical pipe flow model of the wellbore based on the historical vertical pipe flow data and basic wellbore data; and draw dynamic curves of gas outflow under different pipe diameters based on the vertical pipe flow model of the wellbore. Based on the gas inflow dynamic curve and the gas outflow dynamic curve, a correspondence between the average formation pressure and the reasonable gas production rate under different pipe diameters is constructed. Determine the relationship between mean formation pressure and cumulative gas production; Determine the planned gas extraction time and gas extraction volume per unit time within the current cycle of the gas storage facility. Determine the average formation pressure based on the correspondence between the planned gas extraction time, gas extraction volume per unit time, average formation pressure, and cumulative gas extraction volume. Determine the reasonable gas extraction volume based on the correspondence between the average formation pressure, average formation pressure, and reasonable gas extraction volume. Determine the working gas volume of the gas storage facility for the current cycle, and determine the number of gas production wells based on the reasonable gas production volume and the working gas volume; Determining the correspondence between average formation pressure and cumulative gas production includes: Construct a gas production phase material balance model for multiple cycles of injection / production, and determine the correspondence between average formation pressure and cumulative gas production based on the gas production phase material balance model. The step of constructing the correspondence between average formation pressure and reasonable gas production rate under different pipe diameters based on the gas inflow dynamic curve and the gas outflow dynamic curve includes: Obtain the intersection value of the gas inflow dynamic curve and the gas outflow dynamic curve; The correlation between average formation pressure and reasonable gas production rate under different pipe diameters is obtained by fitting the intersection point values. The gas extraction phase material balance model includes: ； in, This represents the initial inventory level during the gas extraction phase of the gas storage facility. This represents the gas volume coefficient at the initial moment of the gas extraction phase. This represents the cumulative water production at time t during the gas extraction phase. This is the formation water volume coefficient; This represents the cumulative gas extraction volume at time t during the gas extraction phase. The gas volume coefficient at time t during the gas extraction stage; This is the water intrusion coefficient; This represents the formation pressure at the initial moment of the gas extraction stage. The formation pressure at time t during the gas extraction stage; Determining the working gas volume of the gas storage facility for the current cycle includes: Construct a movable cushion gas volume state model for the gas storage facility, and determine the movable cushion gas volume based on the movable cushion gas volume state model; The working air volume is determined based on the movable cushion air volume and the initial storage capacity; The movable cushion air volume state model includes: ； in, It is the air volume of the movable cushion; This represents the lower limit of resistance. This is the natural gas deviation coefficient corresponding to the lower limit pressure; Reservoir temperature; Temperature under standard gas conditions; This refers to the pressure of a gas under standard conditions. The volume of movable gas-bearing pores in the gas storage tank.

2. The method for determining the number of gas production wells during the gas production stage of an underground gas storage facility according to claim 1, characterized in that, The step of plotting dynamic curves of gas inflow under different formation pressures based on the historical gas production capacity data includes: A gas well production capacity model is constructed based on the historical gas production capacity data, and dynamic curves of gas inflow under different formation pressures are plotted based on the gas well production capacity model.

3. The method for determining the number of gas production wells in the gas production stage of an underground gas storage facility according to claim 2, characterized in that, The gas well production capacity model includes: ； in, Formation pressure; Bottom hole flowing pressure; This refers to the gas production rate of the gas well. and is a coefficient.

4. The method for determining the number of gas production wells during the gas production stage of an underground gas storage facility according to claim 1, characterized in that, The vertical pipe flow model in the wellbore includes: ； ； in, This refers to the wellhead pressure. The friction coefficient of the pipeline inside the well; The average temperature inside the well; This is the average deviation coefficient within the wellbore; This refers to the gas production rate of the gas well. The inner diameter of the pipe inside the well; The relative density of natural gas; This refers to the depth in the middle of the gas storage facility.

5. The method for determining the number of gas production wells during the gas production stage of an underground gas storage facility according to claim 1, wherein determining the number of gas production wells based on the reasonable gas production volume and the working gas volume includes: The reasonable gas production volume and the working gas volume are input into the gas well number determination model to determine the number of gas wells; The model for determining the number of gas production wells includes: ； in, For working gas volume, To plan the gas extraction time, To ensure a reasonable gas extraction volume.

6. A device for determining the number of gas production wells in the gas production stage of an underground gas storage facility, based on the method for determining the number of gas production wells in the gas production stage of an underground gas storage facility according to any one of claims 1-5, characterized in that, include: The first processing module is used to acquire historical gas production capacity data of gas wells and draw dynamic curves of gas inflow under different formation pressures based on the historical gas production capacity data. The second processing module is used to acquire historical vertical pipe flow data and basic wellbore data of the gas well, construct a vertical pipe flow model of the wellbore based on the historical vertical pipe flow data and basic wellbore data, and draw dynamic curves of gas outflow under different pipe diameters based on the vertical pipe flow model of the wellbore. The module is used to construct the correspondence between average formation pressure and reasonable gas production volume under different pipe diameters based on the gas inflow dynamic curve and the gas outflow dynamic curve. The first determining module is used to determine the correspondence between average formation pressure and cumulative gas production. The second determining module is used to determine the planned gas extraction time and gas extraction volume per unit time within the current cycle of the gas storage facility. It determines the average formation pressure based on the correspondence between the planned gas extraction time, gas extraction volume per unit time, average formation pressure, and cumulative gas extraction volume. It also determines the reasonable gas extraction volume based on the correspondence between the average formation pressure and the reasonable gas extraction volume. The third determining module is used to determine the working gas volume of the gas storage facility in the current cycle, and to determine the number of gas production wells based on the reasonable gas production volume and the working gas volume.

7. An electronic device comprising a processor and a memory storing a computer program, characterized in that, When the processor executes the computer program, it implements the steps of the method for determining the number of gas production wells in the gas production stage of the underground gas storage facility as described in any one of claims 1 to 5.

8. A processor-readable storage medium, characterized in that, The processor-readable storage medium stores a computer program that causes the processor to execute the steps of the method for determining the number of gas production wells in the gas production stage of an underground gas storage facility as described in any one of claims 1 to 5.

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