Method and device for determining the number of injection wells in the injection phase of an underground gas storage

Abstract

This invention relates to the field of gas storage management technology, and provides a method and apparatus for determining the number of injection wells during the injection phase of an underground gas storage facility. The method includes: constructing a correlation between average formation pressure and reasonable injection volume for different pipe diameters based on dynamic curves of gas inflow and outflow; determining the correlation between average formation pressure and cumulative injection volume; determining the average formation pressure based on planned injection time, injection volume per unit time, and the correlation between average formation pressure and cumulative injection volume; determining the reasonable injection volume based on the correlation between average formation pressure and reasonable injection volume; and determining the number of injection wells based on the reasonable injection volume and injection capacity. This ensures efficient injection of gas from pipelines into the underground gas storage facility, while preventing high-speed injection-production rates from damaging the reservoir, thus ensuring the safety of gas storage and providing guidance for planning the gas injection work schedule during the injection phase.

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 injection wells during the injection 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 energy peak shaving and are vital energy reserve facilities for ensuring national gas supply security. Each cycle requires the injection of sufficient natural gas into the storage facility for peak shaving. During the injection phase, the injection wells must ensure efficient injection of gas from the pipeline into the underground storage facility, and the high injection-production rate must not damage the reservoir, thus ensuring the safety of the stored gas. 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 injection wells during the injection stage of an underground gas storage facility.

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

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

[0007] Acquire historical vertical pipe flow data and basic wellbore data of the gas well, and plot dynamic curves of gas injection inflow under different pipe diameters based on the historical vertical pipe flow and basic wellbore data.

[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 injection volume under different pipe diameters is constructed.

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

[0010] Determine the planned gas injection time and gas injection 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 injection time, gas injection volume per unit time, average formation pressure, and cumulative gas injection volume. Determine the reasonable gas injection volume based on the correspondence between the average formation pressure, average formation pressure, and reasonable gas injection volume.

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

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

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

[0014] In one embodiment, the step of plotting dynamic gas injection inflow curves for different pipe diameters based on the historical wellbore vertical flow and basic wellbore data includes:

[0015] A vertical flow model for the wellbore is constructed based on the historical vertical flow and basic wellbore data. Dynamic curves of gas injection inflow under different pipe diameters are then plotted based on the vertical flow model.

[0016] In one embodiment, determining the correspondence between average formation pressure and cumulative gas injection volume includes:

[0017] A gas injection phase material balance model is constructed for multiple cycles of gas injection / production operation, and the correspondence between average formation pressure and cumulative gas injection volume is determined based on the gas injection phase material balance model.

[0018] In one embodiment, constructing the correspondence between average formation pressure and reasonable gas injection volume under different pipe diameters based on the gas injection inflow dynamic curve and the gas injection outflow dynamic curve includes:

[0019] Obtain the intersection value of the gas injection inflow dynamic curve and the gas injection outflow dynamic curve;

[0020] The correlation between average formation pressure and reasonable gas injection volume under different pipe diameters is obtained by fitting the intersection point values.

[0021] In one embodiment, the gas well injection capacity model includes:

[0022]

[0023] Where, p e Formation pressure; p wf q represents the bottom-hole flowing pressure; a and b represent the gas injection rate of the gas well; and a and b are coefficients.

[0024] In one embodiment, the vertical pipe flow model of the wellbore includes:

[0025]

[0026]

[0027] Where, p tfγ 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 injection 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.

[0028] In one embodiment, the gas injection phase material balance model includes:

[0029]

[0030] Among them, G res B represents the initial inventory level during the gas injection phase of the gas storage facility. gi G represents the gas volume coefficient at the initial moment of the injection phase. t B represents the cumulative gas injection volume at time t during the gas injection phase. gt C is the gas volume coefficient at time t during the injection phase; s P is the water intrusion coefficient. i P represents the formation pressure at the initial moment of the gas injection stage. t This represents the formation pressure at time t during the gas injection stage.

[0031] In one embodiment, determining the gas injection capacity of the gas storage facility for the current cycle includes:

[0032] Construct a movable storage capacity state model for the gas storage facility, and determine the movable storage capacity based on the movable storage capacity state model;

[0033] The gas injection capacity is determined based on the movable reservoir capacity and the initial reservoir capacity.

[0034] In one embodiment, the movable warehouse capacity state model includes:

[0035]

[0036] Among them, G max It is the movable storage capacity; p max For upper limit pressure; Z max T is the natural gas deviation coefficient corresponding to the upper 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.

[0037] In one embodiment, determining the number of injection wells based on the reasonable injection volume and the injection capacity includes:

[0038] The reasonable gas injection volume and the gas injection capacity are input into the gas injection well number determination model to determine the number of gas injection wells; the gas injection well number determination model includes:

[0039]

[0040] Among them, G vol q represents the injection capacity, t represents the planned injection time, and q represents the injection volume. g To ensure a reasonable gas injection volume.

[0041] Secondly, the present invention provides a device for determining the number of gas injection wells during the gas injection stage of an underground gas storage facility, characterized in that it comprises:

[0042] The first processing module is used to acquire historical gas injection capacity data of gas wells and draw dynamic curves of gas injection outflow under different formation pressures based on the historical gas injection capacity data.

[0043] The second processing module is used to acquire historical vertical pipe flow data and basic wellbore data of the gas well, and to draw dynamic curves of gas injection inflow under different pipe diameters based on the historical vertical pipe flow data and basic wellbore data.

[0044] The module is used to construct the correspondence between the average formation pressure and the reasonable gas injection volume under different pipe diameters based on the gas injection inflow dynamic curve and the gas injection outflow dynamic curve.

[0045] The first determining module is used to determine the correspondence between average formation pressure and cumulative gas injection volume;

[0046] The second determining module is used to determine the planned gas injection time and gas injection 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 injection time, gas injection volume per unit time, average formation pressure, and cumulative gas injection volume, and determine the reasonable gas injection volume based on the relationship between the average formation pressure and the reasonable gas injection volume.

[0047] The third determining module is used to determine the gas injection capacity of the gas storage facility in the current cycle, and to determine the number of injection wells based on the reasonable gas injection volume and the gas injection capacity.

[0048] 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 injection wells in the gas injection stage of the underground gas storage facility as described in the first aspect.

[0049] 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 injection wells in the injection stage of an underground gas storage facility as described in the first aspect.

[0050] The present invention provides a method, apparatus, electronic equipment, and storage medium for determining the number of injection wells during the injection phase of an underground gas storage facility. It determines the relationship between average formation pressure and reasonable injection volume through formation flow pressure and wellbore flow, and obtains the relationship between average formation pressure and cumulative injection volume during the injection phase of a gas storage facility's multi-cycle injection and production operation. Then, based on these relationships, a reasonable injection volume is determined, and the number of injection wells is determined based on the current cycle's injection capacity and reasonable injection volume. This ensures efficient injection of gas from pipelines into the underground gas storage facility, while preventing high-speed injection and production rates from damaging the reservoir, thus ensuring the safety of gas storage and providing guidance for planning the injection work schedule during the injection phase. Attached Figure Description

[0051] 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.

[0052] Figure 1 This is a flowchart illustrating the method for determining the number of injection wells during the injection stage of an underground gas storage facility provided by the present invention.

[0053] Figure 2 This is a schematic diagram of the inflow / outflow dynamic curve provided by the present invention;

[0054] Figure 3 This is a schematic diagram of the device for determining the number of injection wells during the injection stage of an underground gas storage facility provided by the present invention.

[0055] Figure 4 This is a schematic diagram of the structure of the electronic device provided by the present invention. Detailed Implementation

[0056] 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.

[0057] The following is combined with Figures 1-4 This invention describes a method, apparatus, electronic device, and storage medium for determining the number of injection wells during the injection stage of an underground gas storage facility.

[0058] Figure 1 This invention illustrates a flowchart of a method for determining the number of injection wells during the injection stage of an underground gas storage facility. (See attached diagram.) Figure 1 The method includes:

[0059] 11. Obtain historical gas injection capacity data of gas wells, and plot dynamic curves of gas injection flow under different formation pressures based on historical gas injection capacity data;

[0060] 12. Obtain historical vertical pipe flow data and basic wellbore data of the gas well, and plot the dynamic curve of gas injection inflow under different pipe diameters based on the historical vertical pipe flow data and basic wellbore data;

[0061] 13. Based on the dynamic curves of gas inflow and gas outflow, construct the correspondence between the average formation pressure and the reasonable gas injection rate under different pipe diameters;

[0062] 14. Determine the relationship between mean formation pressure and cumulative gas injection volume;

[0063] 15. Determine the planned gas injection time and gas injection 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 injection time, gas injection volume per unit time, average formation pressure, and cumulative gas injection volume. Determine the reasonable gas injection volume based on the relationship between the average formation pressure, average formation pressure, and reasonable gas injection volume.

[0064] 16. Determine the gas injection capacity of the gas storage facility for the current cycle, and determine the number of injection wells based on the reasonable gas injection volume and capacity.

[0065] 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.

[0066] In this invention, during the gas injection stage, historical gas injection capacity data of the gas well needs to be obtained. This data may include formation pressure, bottom hole flowing pressure, and gas injection volume. The historical gas injection capacity data is then analyzed to fit and plot dynamic curves of gas injection outflow under different formation pressures.

[0067] During the gas injection phase, it is also necessary to acquire historical vertical pipe flow data and basic wellbore data. This historical vertical pipe flow data may include wellhead pressure and injection volume. 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. Then, the historical vertical pipe flow and basic wellbore data are analyzed to fit and plot dynamic gas injection inflow curves for different pipe diameters.

[0068] In this invention, in a coordinate system with gas injection volume as the abscissa and bottom hole pressure as the ordinate, the dynamic curves of gas injection inflow and gas injection outflow can intersect. Based on these intersection points, the correspondence between the average formation pressure and the reasonable gas injection volume under different pipe diameters can be obtained. This correspondence is a functional relationship.

[0069] In this invention, the gas storage facility operates on an annual cycle. At the time of injection, the storage facility already contains natural gas. During each injection and extraction phase of the cycle, a balance needs to be maintained between the existing inventory and the cumulative injection volume. Therefore, by analyzing data such as inventory levels and injection volumes at different injection points within the cycle, the correlation between average formation pressure and cumulative injection volume is determined. This correlation is also a functional relationship, interrelated with the correlation between average formation pressure and a reasonable injection volume.

[0070] In this invention, to determine the number of gas wells currently required for gas injection, it is necessary to clarify the planned gas injection time and injection volume per unit time within the current cycle of the gas storage facility. The planned gas injection time can be the planned number of injection days, and the injection volume per unit time can be the daily or monthly injection volume. The average formation pressure is determined based on the relationship between the planned gas injection time, the injection volume per unit time, and the average formation pressure and cumulative injection volume. Then, the reasonable injection volume is determined based on the relationship between the average formation pressure and the reasonable injection volume. This reasonable injection volume is equivalent to the daily injection volume of a single gas well within a reasonable pressure range that the formation can withstand.

[0071] In this invention, the gas injection capacity of the gas storage facility for the current cycle is determined. This gas injection capacity is the total capacity of natural gas that the gas storage facility can currently receive. Then, the number of injection wells is determined based on the reasonable gas injection volume and the gas injection capacity.

[0072] The method for determining the number of injection wells during the injection phase of an underground gas storage facility provided by this invention determines the relationship between average formation pressure and reasonable gas injection volume through formation flow pressure and wellbore flow, and obtains the relationship between average formation pressure and cumulative gas injection volume of the gas storage facility through the gas injection phase of multi-cycle injection and production operation. Then, based on the reasonable gas injection volume according to the relationship, the number of injection wells is determined based on the gas injection capacity of the current cycle and the reasonable gas injection volume. This ensures efficient injection of gas from the pipeline into the underground gas storage facility, and that the high injection and production rate does not damage the reservoir, thus ensuring the safety of gas storage in the gas storage facility and providing guidance for planning the gas injection work system during the injection phase.

[0073] A further method described above primarily involves explaining the process of plotting dynamic curves of gas injection outflow under different formation pressures based on historical gas injection capacity data, as detailed below:

[0074] A gas well injection capacity model is constructed based on historical gas injection capacity data, and dynamic curves of gas injection outflow under different formation pressures are plotted based on the gas well injection capacity model.

[0075] It should be noted that the gas well injection capacity model is obtained by fitting historical gas injection capacity data. Furthermore, this gas well injection capacity module includes:

[0076]

[0077] Where, p e Formation pressure; p wf q represents the bottom-hole flowing pressure; a and b represent the gas injection rate of the gas well; and a and b are coefficients.

[0078] Based on the gas injection production capacity model of this gas well, dynamic curves of gas injection outflow under different formation pressures are plotted in a coordinate system with gas injection volume as the abscissa and bottom hole flowing pressure as the ordinate.

[0079] A further step in the above method mainly explains the process of plotting dynamic curves of gas injection inflow under different pipe diameters based on historical vertical pipe flow and basic wellbore data, as detailed below:

[0080] A vertical flow model for the wellbore is constructed based on historical vertical flow data and basic wellbore data. Dynamic curves of gas injection inflow under different pipe diameters are then plotted based on the vertical flow model.

[0081] It should be noted that in this invention, a vertical flow model is obtained by fitting historical vertical flow data and basic wellbore data. This vertical flow model includes:

[0082]

[0083]

[0084] 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 injection 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.

[0085] Based on the vertical pipe flow model of the wellbore, dynamic curves of gas injection inflow under different pipe diameters are plotted in a coordinate system with gas injection volume as the abscissa and bottom hole pressure as the ordinate.

[0086] In a further step of the above method, the process of determining the correspondence between mean formation pressure and cumulative gas injection volume is explained, as follows:

[0087] A material balance model for the gas injection stage of multiple gas injection / production cycles was constructed, and the correspondence between the mean formation pressure and the cumulative gas injection volume was determined based on the material balance model for the gas injection stage.

[0088] 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 multiple injection / production operation phases are collected, and then a material balance model for the injection phase of the gas storage facility's multi-cycle injection / production operation is provided based on this data. This injection phase material balance model includes:

[0089]

[0090] Among them, G res B represents the initial inventory level during the gas injection phase of the gas storage facility. gi G represents the gas volume coefficient at the initial moment of the injection phase. t B represents the cumulative gas injection volume at time t during the gas injection phase. gt C is the gas volume coefficient at time t during the injection phase; s P is the water intrusion coefficient. i P represents the formation pressure at the initial moment of the gas injection stage. t This represents the formation pressure at time t during the gas injection stage.

[0091] Based on the material balance model of the gas injection stage, the correspondence between the average formation pressure and the cumulative gas injection volume is extracted.

[0092] A further step in the above method mainly explains the process of constructing the correspondence between average formation pressure and reasonable gas injection volume under different pipe diameters based on the dynamic curves of gas injection inflow and gas injection outflow, as detailed below:

[0093] Obtain the intersection value of the gas injection inflow dynamic curve and the gas injection outflow dynamic curve;

[0094] The correlation between average formation pressure and reasonable gas injection volume under different pipe diameters was obtained by fitting the intersection values.

[0095] It should be noted that in this invention, in a coordinate system with the gas injection rate as the abscissa and the bottom hole flowing pressure as the ordinate, the dynamic curves of gas injection inflow and gas injection outflow can intersect. (See [reference needed]). Figure 2 As shown.

[0096] Curve 1 is the outflow dynamic curve under an average formation pressure of 10 MPa;

[0097] Curve 2 is the outflow dynamic curve under an average formation pressure of 13 MPa;

[0098] Curve 3 is the outflow dynamic curve under an average formation pressure of 16 MPa;

[0099] Curve 4 is the outflow dynamic curve under an average formation pressure of 19 MPa;

[0100] Curve 5 is the outflow dynamic curve under an average formation pressure of 22 MPa;

[0101] Curve 6 is the inflow dynamic curve with an inner diameter of 3.5 inches in the generating pipe;

[0102] Curve 7 is the inflow dynamic curve with an inner diameter of 4.5 in the generating pipe;

[0103] Curve 8 is the inflow dynamic curve with an inner diameter of 5.5 in the generating pipe.

[0104] The relationship between average formation pressure and reasonable gas injection volume under different pipe diameters can be obtained by fitting these intersection points.

[0105] A further method described above primarily explains the process of determining the gas injection capacity of the gas storage facility for the current cycle, as follows:

[0106] Construct a movable storage capacity state model for the gas storage facility, and determine the movable storage capacity based on the movable storage capacity state model;

[0107] The injection capacity is determined based on the movable reservoir capacity and the initial reservoir capacity.

[0108] It should be noted that, in this invention, the movable warehouse capacity state model includes:

[0109]

[0110] Among them, G max It is the movable storage capacity; p max For upper limit pressure; Z max T is the natural gas deviation coefficient corresponding to the upper 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.

[0111] Based on the movable reservoir capacity state model, the gas injection capacity can be determined by the movable reservoir capacity and the initial reservoir capacity.

[0112] The further method described above mainly explains the process of determining the number of injection wells based on reasonable gas injection volume and capacity, as follows:

[0113] The appropriate gas injection volume and gas injection capacity are input into the gas injection well number determination model to determine the number of gas injection wells; the gas injection well number determination model includes:

[0114]

[0115] Among them, G vol q represents the injection capacity, t represents the planned injection time, and q represents the injection volume. g To ensure reasonable gas injection volume

[0116] This invention introduces a movable storage capacity and provides a method for defining the gas injection capacity during the gas injection stage. Based on the gas injection capacity of the gas storage, the number of gas injection wells in the gas injection stage is determined to ensure that the gas from the pipeline is injected into the underground gas storage efficiently, and that the high injection and production rate does not damage the reservoir, thus ensuring the safety of the gas storage in the gas storage.

[0117] The following describes the device for determining the number of injection wells in the injection stage of an underground gas storage facility provided by the present invention. The device for determining the number of injection wells in the injection stage of an underground gas storage facility described below can be referred to in correspondence with the method for determining the number of injection wells in the injection stage of an underground gas storage facility described above.

[0118] Figure 3 This diagram illustrates the structure of a device for determining the number of injection wells during the injection 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...

[0119] The first processing module 31 is used to acquire historical gas injection capacity data of gas wells and draw dynamic curves of gas injection outflow under different formation pressures based on the historical gas injection capacity data.

[0120] The second processing module 32 is used to acquire historical vertical pipe flow data and basic wellbore data of the gas well, and to draw dynamic curves of gas injection inflow under different pipe diameters based on the historical vertical pipe flow data and basic wellbore data.

[0121] Module 33 is used to construct the correspondence between average formation pressure and reasonable gas injection volume under different pipe diameters based on the gas injection inflow dynamic curve and the gas injection outflow dynamic curve;

[0122] The first determining module 34 is used to determine the correspondence between average formation pressure and cumulative gas injection volume;

[0123] The second determining module 35 is used to determine the planned gas injection time and gas injection 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 injection time, gas injection volume per unit time, average formation pressure, and cumulative gas injection volume. It also determines the reasonable gas injection volume based on the relationship between the average formation pressure, average formation pressure, and reasonable gas injection volume.

[0124] The third determining module 36 is used to determine the gas injection capacity of the gas storage facility in the current cycle, and to determine the number of gas injection wells based on the reasonable gas injection volume and gas injection capacity.

[0125] In a further embodiment of the above-described apparatus, the first processing module is specifically used for:

[0126] A gas well injection capacity model is constructed based on the historical gas injection capacity data, and dynamic curves of gas injection outflow under different formation pressures are plotted based on the gas well injection capacity model.

[0127] In a further embodiment of the above-described apparatus, the second processing module is specifically used for:

[0128] A vertical flow model for the wellbore is constructed based on historical vertical flow data and basic wellbore data. Dynamic curves of gas injection inflow under different pipe diameters are then plotted based on the vertical flow model.

[0129] In a further embodiment of the above-described apparatus, the first determining module is specifically used for:

[0130] A gas injection phase material balance model is constructed for multiple cycles of gas injection / production operation, and the correspondence between average formation pressure and cumulative gas injection volume is determined based on the gas injection phase material balance model.

[0131] In a further embodiment of the above apparatus, the construction module is specifically used for:

[0132] Obtain the intersection value of the gas injection inflow dynamic curve and the gas injection outflow dynamic curve;

[0133] The correlation between average formation pressure and reasonable gas injection volume under different pipe diameters is obtained by fitting the intersection point values.

[0134] In a further embodiment of the aforementioned apparatus, the gas well injection production capacity model includes:

[0135]

[0136] Where, p e Formation pressure; p wf q represents the bottom-hole flowing pressure; a and b represent the gas injection rate of the gas well; and a and b are coefficients.

[0137] In a further embodiment of the above-mentioned apparatus, the vertical pipe flow model in the wellbore includes:

[0138]

[0139]

[0140] 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 injection 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.

[0141] In a further embodiment of the above-mentioned apparatus, the mass balance model for the gas injection stage includes:

[0142]

[0143] Among them, G res B represents the initial inventory level during the gas injection phase of the gas storage facility. gi G represents the gas volume coefficient at the initial moment of the injection phase. t B represents the cumulative gas injection volume at time t during the gas injection phase. gt C is the gas volume coefficient at time t during the injection phase; s P is the water intrusion coefficient. i P represents the formation pressure at the initial moment of the gas injection stage. t This represents the formation pressure at time t during the gas injection stage.

[0144] In a further part of the above-mentioned device, the third determining module, in the process of determining the gas injection capacity of the gas storage tank for the current cycle, is specifically used for:

[0145] Construct a movable storage capacity state model for the gas storage facility, and determine the movable storage capacity based on the movable storage capacity state model;

[0146] The gas injection capacity is determined based on the movable reservoir capacity and the initial reservoir capacity.

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

[0148] The reasonable gas injection volume and gas injection capacity are input into the gas injection well number determination model to determine the number of gas injection wells; the gas injection well number determination model includes:

[0149]

[0150] Among them, G vol q represents the injection capacity, t represents the planned injection time, and q represents the injection volume. g To ensure a reasonable gas injection 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 injection wells during the injection phase of an underground gas storage facility provided by this invention determines the relationship between average formation pressure and reasonable gas injection volume through formation flow pressure and wellbore flow, and obtains the relationship between average formation pressure and cumulative gas injection volume of the gas storage facility through the gas injection phase of multi-cycle injection and production operation. Then, it determines the reasonable gas injection volume based on the relationship, and determines the number of injection wells based on the current cycle's gas injection capacity and reasonable gas injection volume. This ensures efficient injection of gas from pipelines into the underground gas storage facility, and that the high injection and production rate does not damage the reservoir, thus ensuring the safety of gas storage in the gas storage facility and providing guidance for planning the gas injection work system during the injection phase.

[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, wherein the processor 41, the communication interface 42, and the memory 43 communicate with each other through 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 injection wells during the injection phase of the underground gas storage facility. These steps include, for example: acquiring historical injection capacity data of the gas wells; plotting injection flow out dynamic curves under different formation pressures based on the historical injection capacity data; acquiring historical vertical pipe flow data and basic wellbore data of the gas wells; plotting injection inflow dynamic curves under different pipe diameters based on the historical vertical pipe flow data and basic wellbore data; constructing a correspondence between average formation pressure and reasonable injection volume under different pipe diameters based on the injection inflow dynamic curves and injection flow out dynamic curves; determining the correspondence between average formation pressure and cumulative injection volume; determining the planned injection time and injection volume per unit time within the current cycle of the gas storage facility; determining the average formation pressure based on the planned injection time, injection volume per unit time, and the correspondence between average formation pressure and cumulative injection volume; determining the reasonable injection volume based on the correspondence between average formation pressure and average formation pressure and reasonable injection volume; determining the injection capacity of the gas storage facility in the current cycle; and determining the number of injection wells based on the reasonable injection volume and injection capacity.

[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 injection wells in the injection stage of an underground gas storage facility provided by the above methods. This method includes: acquiring historical gas injection capacity data of the gas wells; drawing dynamic curves of gas injection flow under different formation pressures based on the historical gas injection capacity data; acquiring historical vertical pipe flow data and basic wellbore data of the gas wells; and drawing curves of different pipe diameters based on the historical vertical pipe flow data and basic wellbore data. The following steps are taken: First, determine the dynamic curve of gas injection inflow. Second, construct the correspondence between average formation pressure and reasonable gas injection volume for different pipe diameters based on the dynamic curves of gas injection inflow and outflow. Third, determine the correspondence between average formation pressure and cumulative gas injection volume. Fourth, determine the planned gas injection time and gas injection volume per unit time within the current cycle of the gas storage facility. Fifth, determine the average formation pressure based on the planned gas injection time, gas injection volume per unit time, and the correspondence between average formation pressure and cumulative gas injection volume. Sixth, determine the reasonable gas injection volume based on the correspondence between average formation pressure and reasonable gas injection volume. Finally, determine the gas injection capacity of the gas storage facility for the current cycle. Seventh, determine the number of injection wells based on the reasonable gas injection volume and the injection capacity.

[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 injection wells during the injection stage of an underground gas storage facility provided in the above embodiments. For example, it includes: acquiring historical injection capacity data of the gas wells; plotting dynamic curves of injection gas outflow under different formation pressures based on the historical injection capacity data; acquiring historical vertical pipe flow data and basic wellbore data of the gas wells; plotting dynamic curves of injection gas inflow under different pipe diameters based on the historical vertical pipe flow data and basic wellbore data; and plotting dynamic curves of injection gas inflow under different pipe diameters based on the injection capacity data. The dynamic curves of gas inflow and gas outflow are used to establish the correspondence between average formation pressure and reasonable gas injection volume under different pipe diameters; the correspondence between average formation pressure and cumulative gas injection volume is determined; the planned gas injection time and gas injection volume per unit time in the current cycle of the gas storage are determined; the average formation pressure is determined based on the planned gas injection time, gas injection volume per unit time, and the correspondence between average formation pressure and cumulative gas injection volume; the reasonable gas injection volume is determined based on the correspondence between average formation pressure and average formation pressure and reasonable gas injection volume; the gas injection capacity of the gas storage in the current cycle is determined; and the number of gas injection wells is determined based on the reasonable gas injection volume and the gas injection capacity.

[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 injection wells in the injection phase of a gas storage reservoir, characterized in that, include: Obtain historical gas injection capacity data of gas wells, and plot dynamic curves of gas injection outflow under different formation pressures based on the historical gas injection capacity data. Acquire historical vertical pipe flow data and basic wellbore data of the gas well, and plot dynamic curves of gas injection inflow under different pipe diameters based on the historical vertical pipe flow and basic wellbore data. Based on the gas inflow dynamic curve and the gas outflow dynamic curve, a correspondence between the average formation pressure and the reasonable gas injection volume under different pipe diameters is constructed. Determine the relationship between mean formation pressure and cumulative gas injection volume; Determine the planned gas injection time and gas injection 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 injection time, gas injection volume per unit time, average formation pressure, and cumulative gas injection volume. Determine the reasonable gas injection volume based on the correspondence between the average formation pressure, average formation pressure, and reasonable gas injection volume. Determine the gas injection capacity of the gas storage facility for the current cycle, and determine the number of injection wells based on the reasonable gas injection volume and the gas injection capacity; The step of plotting dynamic curves of gas injection outflow under different formation pressures based on the historical gas injection capacity data includes: A gas well gas injection capacity model is constructed based on the historical gas injection capacity data, and dynamic curves of gas injection outflow under different formation pressures are plotted based on the gas well gas injection capacity model. Determining the correspondence between average formation pressure and cumulative gas injection includes: Construct a gas injection phase material balance model for multiple cycles of gas injection / production operation, and determine the correspondence between average formation pressure and cumulative gas injection volume based on the gas injection phase material balance model; The gas injection phase material balance model includes: ； wherein, is the initial inventory of the gas storage at the beginning of the injection phase, is the gas volume factor at the beginning of the injection phase; is the cumulative gas injection at time t of the injection phase; is the gas volume factor at time t of the injection phase; is the water influx coefficient; is the formation pressure at the beginning of the injection phase; is the formation pressure at time t of the injection phase; Determining the gas injection capacity of the gas storage facility for the current cycle includes: Construct a movable storage capacity state model for the gas storage facility, and determine the movable storage capacity based on the movable storage capacity state model; The gas injection capacity is determined based on the movable reservoir capacity and the initial reservoir capacity; The movable warehouse capacity state model includes: ； in, It is the movable storage capacity; Upper limit pressure; This is the natural gas deviation coefficient corresponding to the upper limit pressure; Reservoir temperature; Temperature under standard gas conditions; This refers to the pressure of a gas under standard conditions. The movable gas-containing pore volume of the gas storage facility; The step of determining the number of injection wells based on the reasonable gas injection volume and the gas injection capacity includes: The reasonable gas injection volume and the gas injection capacity are input into the gas injection well number determination model to determine the number of gas injection wells; the gas injection well number determination model includes: ； in, For the gas injection capacity, For the planned gas injection time, To ensure a reasonable gas injection volume.

2. The method for determining the number of injection wells during the injection stage of an underground gas storage facility according to claim 1, characterized in that, The process of plotting dynamic gas injection inflow curves for different pipe diameters based on the historical vertical pipe flow and basic wellbore data includes: A vertical flow model for the wellbore is constructed based on the historical vertical flow and basic wellbore data. Dynamic curves of gas injection inflow under different pipe diameters are then plotted based on the vertical flow model.

3. The method for determining the number of injection wells during the injection stage of an underground gas storage facility according to claim 1, characterized in that, The step of constructing the correspondence between average formation pressure and reasonable gas injection volume under different pipe diameters based on the gas injection inflow dynamic curve and the gas injection outflow dynamic curve includes: Obtain the intersection value of the gas injection inflow dynamic curve and the gas injection outflow dynamic curve; The correlation between average formation pressure and reasonable gas injection volume under different pipe diameters is obtained by fitting the intersection point values.

4. The method for determining the number of injection wells during the injection stage of an underground gas storage facility according to claim 1, characterized in that, The gas well injection capacity model includes: ； in, Formation pressure; Bottom hole flowing pressure; This refers to the gas injection rate of the gas well. and is a coefficient.

5. The method for determining the number of injection wells during the injection stage of an underground gas storage facility according to claim 2, 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 injection 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.

6. A device for determining the number of injection wells in the injection stage of an underground gas storage facility, based on the method for determining the number of injection wells in the injection 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 injection capacity data of gas wells and draw dynamic curves of gas injection outflow under different formation pressures based on the historical gas injection capacity data. The second processing module is used to acquire historical vertical pipe flow data and basic wellbore data of the gas well, and to draw dynamic curves of gas injection inflow under different pipe diameters based on the historical vertical pipe flow data and basic wellbore data. The module is used to construct the correspondence between the average formation pressure and the reasonable gas injection volume under different pipe diameters based on the gas injection inflow dynamic curve and the gas injection outflow dynamic curve. The first determining module is used to determine the correspondence between average formation pressure and cumulative gas injection volume; The second determining module is used to determine the planned gas injection time and gas injection 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 injection time, gas injection volume per unit time, average formation pressure, and cumulative gas injection volume, and determine the reasonable gas injection volume based on the relationship between the average formation pressure and the reasonable gas injection volume. The third determining module is used to determine the gas injection capacity of the gas storage facility in the current cycle, and to determine the number of injection wells based on the reasonable gas injection volume and the gas injection capacity.

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 injection wells in the injection stage of an 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 perform the steps of the method for determining the number of injection wells during the injection stage of an underground gas storage facility as described in any one of claims 1 to 5.

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