A method, device and apparatus for calculating wellhead gas injection pressure and a readable storage medium

Abstract

The present invention relates to the technical field of oil and gas field development, and in particular to a method, device and equipment for calculating wellhead gas injection pressure and a readable storage medium, the method comprising: obtaining basic information of an oil reservoir, the basic information of the oil reservoir comprising first basic information and second basic information; calculating an oil production index and a formation gas absorption index according to the first basic information; constructing a bottomhole flow pressure model, and bringing the oil production index and the formation gas absorption index into the bottomhole flow pressure model to calculate the bottomhole flow pressure of a gas injection well; calculating the wellhead gas injection pressure according to the bottomhole flow pressure of the gas injection well and the second basic information; the present invention applies some simple and easily available application data and the relationship between the oil production index and the gas absorption index according to the law of oil and gas seepage in the formation, and constructs a bottomhole flow pressure model, thereby directly calculating the bottomhole flow pressure of the gas injection well without test injection data, and then calculating the wellhead gas injection pressure.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas field development, and in particular to a method, device and equipment for calculating wellhead gas injection pressure, and a readable storage medium. Background Art

[0002] As an effective method for enhancing oil recovery, gas flooding not only maintains formation pressure but also enables mass transfer of injected gas through gravity displacement, capillary drive, dispersion / diffusion, and pressure drive, ultimately recovering large quantities of remaining oil. The design of gas injection pressure is a key parameter in the design of a gas injection development plan for an oil reservoir.

[0003] In the existing calculation of wellhead gas injection pressure, a large amount of test injection data is required to measure the bottomhole flowing pressure, so as to give a reasonable wellhead gas injection pressure. However, obtaining test injection data requires a large number of experiments, which is time-consuming and laborious. Summary of the Invention

[0004] The object of the present invention is to provide a method, device, equipment and readable storage medium for calculating wellhead gas injection pressure to improve the above-mentioned problems.

[0005] In order to achieve the above objectives, the embodiments of the present application provide the following technical solutions:

[0006] On the one hand, an embodiment of the present application provides a method for calculating wellhead gas injection pressure, the method comprising: obtaining basic reservoir information, the basic reservoir information comprising first basic information and second basic information; calculating the oil production index and the formation gas absorption index respectively based on the first basic information; constructing a bottomhole flow pressure model, and bringing the oil production index and the formation gas absorption index into the bottomhole flow pressure model to calculate the bottomhole flow pressure of the gas injection well; calculating the wellhead gas injection pressure based on the bottomhole flow pressure of the gas injection well and the second basic information.

[0007] Optionally, the calculating the oil recovery index and the formation gas absorption index based on the first basic information respectively includes:

[0008] Retrieving the first basic information, wherein the first basic information includes daily oil production of the oil well, production pressure difference of the oil well, crude oil viscosity, crude oil volume coefficient, injected gas viscosity, gas volume coefficient, and endpoint values of an oil-gas relative permeability curve;

[0009] Calculating the oil production index based on the daily oil production of the oil well and the production pressure difference of the oil well;

[0010] The formation gas absorption index is calculated based on the crude oil viscosity, the crude oil volume coefficient, the injected gas viscosity, the gas volume coefficient, the endpoint value of the oil-gas relative permeability curve and the oil recovery index.

[0011] Optionally, the bottom hole flow pressure model is Where, P wf is the bottom hole flowing pressure of the gas injection well; P r is the formation static pressure; P o is atmospheric pressure; Q g P o Daily gas injection volume under pressure; J g is the formation aspiration index.

[0012] Optionally, calculating the wellhead gas injection pressure according to the bottom hole flowing pressure of the gas injection well and the second basic information includes:

[0013] Retrieving the second basic information, the second basic information including the gas friction coefficient, the daily gas injection volume, the average wellbore temperature, the average gas deviation factor in the wellbore, the inner diameter of the oil pipe, the relative density of the injected gas, and the depth of the middle of the oil layer;

[0014] The gas friction coefficient, daily gas injection volume, average wellbore temperature, average gas deviation factor in the wellbore, inner diameter of the oil pipe, relative density of the injected gas, depth of the middle oil layer and bottom hole flow pressure of the gas injection well are substituted into the gas vertical pipe flow energy equation to calculate the wellhead gas injection pressure.

[0015] In a second aspect, this embodiment provides a wellhead gas injection pressure calculation device, characterized in that the device includes:

[0016] A first acquisition module is used to acquire basic reservoir information, where the basic reservoir information includes first basic information and second basic information;

[0017] a first calculation module, configured to calculate an oil recovery index and a formation gas absorption index based on the first basic information;

[0018] A second calculation module is used to construct a bottom hole flow pressure model, and bring the oil production index and the formation gas absorption index into the bottom hole flow pressure model to calculate the bottom hole flow pressure of the gas injection well;

[0019] The third calculation module is used to calculate the wellhead gas injection pressure according to the bottom hole flowing pressure of the gas injection well and the second basic information.

[0020] Optionally, the first calculation module includes:

[0021] a first retrieving unit, configured to retrieve the first basic information, wherein the first basic information includes daily oil production of the oil well, production pressure difference of the oil well, crude oil viscosity, crude oil volume coefficient, injected gas viscosity, gas volume coefficient, and endpoint values of an oil-gas relative permeability curve;

[0022] a first calculation unit, configured to calculate the oil production index according to the daily oil production of the oil well and the production pressure difference of the oil well;

[0023] The second calculation unit is used to calculate the formation gas absorption index according to the crude oil viscosity, the crude oil volume coefficient, the injected gas viscosity, the gas volume coefficient, the endpoint value of the oil-gas relative permeability curve and the oil production index.

[0024] Optionally, the third calculation module includes:

[0025] a second retrieving unit, configured to retrieve the second basic information, wherein the second basic information includes a gas friction coefficient, a daily gas injection volume, an average wellbore temperature, an average gas deviation factor in the wellbore, an inner diameter of the oil pipe, a relative density of the injected gas, and a depth to the middle of the oil layer;

[0026] The third calculation unit is used to bring the gas friction coefficient, daily gas injection volume, average wellbore temperature, average gas deviation factor in the wellbore, inner diameter of the oil pipe, relative density of the injected gas, middle depth of the oil layer and bottom hole flow pressure of the gas injection well into the gas vertical pipe flow energy equation to calculate the wellhead gas injection pressure.

[0027] In a third aspect, an embodiment of the present application provides a device for calculating wellhead gas injection pressure, the device comprising a memory and a processor. The memory is configured to store a computer program; the processor is configured to implement the steps of the wellhead gas injection pressure calculation method described above when executing the computer program.

[0028] In a fourth aspect, an embodiment of the present application provides a readable storage medium having a computer program stored thereon, and when the computer program is executed by a processor, the steps of the above-mentioned wellhead gas injection pressure calculation method are implemented.

[0029] The beneficial effects of the present invention are:

[0030] The present invention is based on the oil and gas seepage law in the formation, applies some easily available application data and the relationship between the oil production index and the gas absorption index, and constructs a bottom hole flow pressure model, thereby realizing the direct calculation of the gas injection bottom hole flow pressure in the absence of test injection data, and then calculating the wellhead gas injection pressure.

[0031] Secondly, the bottom hole pressure model in the present invention takes the gas slippage effect into account, overcoming the drawback of directly applying the oil well production equation to describe the gas seepage in the reservoir, making the calculated gas injection bottom hole pressure closer to the real number, that is, more accurate.

[0032] Other features and advantages of the present invention will be described in the following description, and in part will become apparent from the description, or understood by practicing the embodiments of the present invention. The purposes and other advantages of the present invention can be realized and obtained by the structures particularly pointed out in the written description, claims, and drawings. BRIEF DESCRIPTION OF THE DRAWINGS

[0033] In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the following briefly introduces the drawings required for use in the embodiments. It should be understood that the following drawings only illustrate certain embodiments of the present invention and therefore should not be regarded as limiting the scope. For ordinary technicians in this field, other relevant drawings can be obtained based on these drawings without paying any creative work.

[0034] Figure 1 This is a flow chart of a method for calculating wellhead gas injection pressure according to an embodiment of the present invention;

[0035] Figure 2 This is a structural diagram of a wellhead gas injection pressure calculation device applicable to a data initiation node according to an embodiment of the present invention;

[0036] Figure 3 This is a structural diagram of a wellhead gas injection pressure calculation device described in an embodiment of the present invention;

[0037] Figure 4 is a graph showing changes in gas injection pressure during oilfield gas injection construction according to an embodiment of the present invention;

[0038] Figure 5 1 is an oil-gas relative permeability curve diagram in an oil well according to an embodiment of the present invention. DETAILED DESCRIPTION

[0039] In order to make the purpose, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are part of the embodiments of the present invention, not all of the embodiments. The components of the embodiments of the present invention generally described and shown in the drawings herein can be arranged and designed in various different configurations. Therefore, the following detailed description of the embodiments of the present invention provided in the drawings is not intended to limit the scope of the claimed invention, but merely represents selected embodiments of the present invention. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making creative work are within the scope of protection of the present invention.

[0040] It should be noted that similar reference numerals or letters represent similar items in the following drawings. Therefore, once an item is defined in one drawing, it does not need to be further defined or explained in subsequent drawings. At the same time, in the description of the present invention, the terms "first", "second", etc. are only used to distinguish the description and should not be understood as indicating or implying relative importance.

[0041] Example 1

[0042] like Figure 1 As shown, this embodiment provides a method for calculating wellhead gas injection pressure, which includes step S1, step S2, step S3 and step S4.

[0043] Step S1. Obtaining basic reservoir information, the basic reservoir information including first basic information and second basic information. In this embodiment, the basic reservoir information includes crude oil viscosity, crude oil volume coefficient, injected gas viscosity, gas volume coefficient, formation static pressure, gas friction coefficient, daily gas injection volume, average wellbore temperature, average gas deviation factor in the wellbore, tubing inner diameter, relative density of injected gas, middle depth of oil layer, endpoint value of oil-gas relative permeability curve, daily oil production of oil well, oil well production pressure difference, etc.

[0044] The first basic information includes: daily oil production of the oil well, oil well production pressure difference, crude oil viscosity, crude oil volume coefficient, injected gas viscosity, gas volume coefficient and the endpoint value of the oil-gas relative permeability curve; the second basic information includes: gas friction coefficient, daily gas injection volume, average wellbore temperature, average gas deviation factor in the wellbore, inner diameter of the oil pipe, relative density of the injected gas and depth of the middle oil layer;

[0045] Step S2. Calculating the oil recovery index and the formation gas absorption index based on the first basic information;

[0046] In this embodiment, the specific calculation method of step S2 can be:

[0047] Step S21. Retrieve the first basic information, which includes the daily oil production of the oil well, the production pressure difference of the oil well, the crude oil viscosity, the crude oil volume coefficient, the injected gas viscosity, the gas volume coefficient, and the endpoint values of the oil-gas relative permeability curve;

[0048] Step S22. Calculating the oil production index based on the daily oil production of the oil well and the production pressure difference of the oil well;

[0049] The specific calculation method in step S22 may be:

[0050] J o =Q o / ΔP o (1);

[0051] Where, J o is the oil recovery index, m 3 / d / MPa;Q o is the daily oil production of the oil well, m 3 / d;ΔP o is the oil well production pressure difference, MPa;

[0052] The oil recovery index can be calculated according to the above calculation formula;

[0053] Step S23. Calculate the formation gas absorption index based on the crude oil viscosity, the crude oil volume coefficient, the injected gas viscosity, the gas volume coefficient, the endpoint value of the oil-gas relative permeability curve, and the oil recovery index;

[0054] In step S23, the specific calculation method may be:

[0055]

[0056] Where, J g is the suction index, m 3 / d / MPa;J o is the oil recovery index, m 3 / d / MPa;(K rg )S or is the relative permeability of the gas phase at residual oil saturation, dimensionless; (K ro )S go is the relative permeability of the oil phase at the critical gas saturation, dimensionless; μ o is the crude oil viscosity, mPa·s; μ g is the viscosity of the injected gas, mPa·s; B o is the volume coefficient of crude oil, m 3 / m 3 ; B g is the volume coefficient of injected gas, m 3 / m 3 ;

[0057] The formation air absorption index can be calculated by the above calculation formula (2);

[0058] Step S3. constructing a bottom hole flow pressure model, and bringing the oil production index and the formation gas absorption index into the bottom hole flow pressure model to calculate the bottom hole flow pressure of the gas injection well;

[0059] In this embodiment, the bottom hole flow pressure model may be:

[0060] Where, P wf is the bottom hole flowing pressure of the gas injection well; P r is the formation static pressure; P o is atmospheric pressure; Q g P o Daily gas injection volume under pressure; J g is the formation gas absorption index. It should be noted that this model takes the gas slippage effect into account, overcoming the drawback of directly applying the oil well production equation to describe the gas seepage in the reservoir, making the calculated gas injection well bottom flow pressure closer to the real number, that is, more accurate;

[0061] It should be noted that the specific derivation and construction method of the bottom hole flow pressure model can be:

[0062] Typically, after obtaining the formation aspiration index, combined with the daily gas injection volume and formation static pressure, the bottomhole flowing pressure of the gas injection well can be calculated based on the oil well production equation. However, since the pressure at each section of the rock length varies when gas seeps through the rock, the volume flow rate of gas flowing through the rock varies at each point within the rock, and it continuously expands and increases in the direction of decreasing pressure. Therefore, the flow state of gas at any point in the rock should be considered to be expressed using the differential form of Darcy's law:

[0063]

[0064] Where k g is the gas permeability, μm 2 ; A is the cross-sectional area of the rock sample, cm 2 ; μ is the gas viscosity, mPa.s; L is the length of the rock sample, cm. In the above calculation formula (3), if it is assumed that the mass flow rate of the gas flowing through each section is constant, then according to the Boyle-Malliott law, the relationship between the volume flow rate of the gas and the pressure under isothermal conditions can be expressed as:

[0065]

[0066] Where, Q, Q o are p and p respectively o Gas volume flow rate under pressure, cm 3 / s;

[0067] By separating the variables and integrating the calculation formula (3), and substituting it into the existing oil well production equation, an improved oil well productivity equation can be obtained, wherein the improved oil well productivity equation is the bottom hole flow pressure model described in this embodiment;

[0068]

[0069] in,

[0070] Where, P wf is the bottom hole pressure of the gas injection well, MPa; P r is the formation static pressure, MPa; P o is atmospheric pressure, MPa; Q g P o Daily gas injection volume under pressure, m 3 / d;J g is the formation aspiration index, m 3 / d / MPa;

[0071] The above calculation formula (5) can be used to calculate the bottom hole pressure of the gas injection well more accurately compared with the traditional oil well production equation.

[0072] It should be noted that the traditional oil well production equation is:

[0073]

[0074] Where, P wf is the bottom hole pressure of the gas injection well, MPa; P r is the formation static pressure, MPa; Q g is the daily gas injection volume, m 3 / d;J g is the formation aspiration index, m 3 / d / MPa;

[0075] Step S4. Calculating the wellhead gas injection pressure based on the bottom hole flowing pressure of the gas injection well and the second basic information;

[0076] In this embodiment, the specific calculation method for calculating the wellhead gas injection pressure according to the bottom hole flowing pressure of the gas injection well and the second basic information in step S4 may be:

[0077] Step S41. Retrieve the second basic information, the second basic information including the gas friction coefficient, daily gas injection volume, average wellbore temperature, average gas deviation factor in the wellbore, inner diameter of the oil pipe, relative density of the injected gas, and depth of the middle of the oil layer;

[0078] Step S42. Calculate the wellhead gas injection pressure by substituting the gas friction coefficient, daily gas injection rate, average wellbore temperature, average gas deviation factor in the wellbore, inner diameter of the oil pipe, relative density of the injected gas, mid-layer depth, and bottomhole pressure of the gas injection well into the vertical pipe gas flow energy equation.

[0079] The specific calculation method may be:

[0080] The gas friction coefficient, daily gas injection volume, average wellbore temperature, average gas deviation factor in the wellbore, inner diameter of the oil pipe, relative density of the injected gas, depth of the middle oil layer and the bottom hole flow pressure of the gas injection well calculated in the above steps are used to apply the gas vertical pipe flow energy equation to determine the reasonable wellhead gas injection pressure P wh :

[0081]

[0082] in,

[0083] s=0.03415γ g ·H / (T av ·Z av ) (9)

[0084] C2=1.3243·λ2·(q g ·Tav ·Z av ) 2 (10)

[0085]

[0086] Where, P wh is the wellhead gas injection pressure, MPa; P wf is the bottom hole flowing pressure of the gas injection well, MPa; γ g is the relative density of gas (air = 1.0); H is the depth of the middle of the gas layer, m; T av is the average temperature of the air flow in the vertical well (average value of the wellhead and the bottom of the well), K; Z av is the average airflow P in the well av and T av The gas deviation coefficient under the condition of λ2 is the annular resistance coefficient; q g is the gas production or gas injection volume of the gas well, 10 4 m 3 / d; D1 is the inner diameter of the casing, cm; D2 is the outer diameter of the oil pipe, cm;

[0087] Secondly, in this embodiment, the effective diameter of the wellbore can be determined according to different casing / tubing diameters, and then the annular resistance coefficient of the wellbore can be determined according to Table 1:

[0088]

[0089] Table 1 Annular resistance coefficient data table

[0090] In this implementation, based on the oil and gas seepage laws in the formation, some easily available application data and the relationship between the oil production index and the gas absorption index were applied, and a bottom hole flow pressure model was constructed. This made it possible to directly calculate the injection bottom hole flow pressure without test injection data, and then calculate the wellhead gas injection pressure.

[0091] Example 2

[0092] To facilitate understanding of the scheme and effects of the embodiments of the present invention, a specific application example is given below. Those skilled in the art should understand that this example is only for facilitating understanding of the present invention, and any specific details thereof are not intended to limit the present invention in any way.

[0093] Basic reservoir data: The reservoir is at a medium depth of 2,450 meters, with a formation temperature of 44.4 to 66.4°C, a geothermal gradient of 1.68 to 2.07°C / 100 meters, a formation pressure of 13.67 to 23.95 MPa, and a pressure coefficient of 0.99 to 1.05. Porosity ranges from 8.3% to 19.84%, with an average of 14.24%, and permeability ranges from 0.91 to 243 mD, with an average of 41.47 mD. Crude oil density ranges from 0.8660 to 0.8859 g / cm³, viscosity from 7.51 to 28.3 mPa.s, volume coefficient averaging 1.0677, and initial gas-oil ratio averaging 12.2 m³ / m³. Test production data from Well H in this reservoir include an effective thickness of 13.2 meters, a permeability of 8.59 mD, a daily oil production of 5.96 m³ / d, and an oil recovery index of 0.4 m³ / dMPa.

[0094] The oil-gas relative permeability curve of the reservoir was fitted through the relative permeability experiment, such as Figure 5 As shown, the gas phase relative permeability at residual oil saturation, the oil phase relative permeability at critical gas saturation, crude oil viscosity, crude oil volume coefficient, gas viscosity and volume coefficient obtained from the phase permeability curve are substituted into formula (2) to calculate the gas production index of 2083.4 m3 / dMPa.

[0095] The Eclipse numerical simulation software was used to simulate gas injection development under reservoir conditions, and the optimal daily gas injection rate was 28,800 m3 / d.

[0096] Substituting the daily gas injection volume, formation pressure and gas absorption index of the gas injection well into formula (5), the bottom flow pressure of the gas injection well is calculated to be 30.74 MPa.

[0097] Substituting the parameters such as the bottom flow pressure of the gas injection well, the daily gas injection volume, and the average wellbore temperature into formula (8), the reasonable wellhead gas injection pressure is calculated to be 24.3 MPa.

[0098] Figure 4 A graph showing the injection pressure during the oilfield gas injection process according to one embodiment of the present invention is shown. As shown, the injection pressure ranges from 21.7 to 24.6 MPa, with a normal injection pressure of around 23.7 MPa. The on-site pressure is consistent with the predicted injection pressure of 24.3 MPa.

[0099] Table 2 compares the wellhead injection pressure calculated using the unmodified oil well productivity equation and the wellhead injection pressure calculated using the improved method in the example. The relative error between the wellhead injection pressure calculated in this example and the actual wellhead injection pressure is only 2.53%, far lower than the 26.75% relative error in wellhead injection pressure calculated using the traditional method.

[0100]

[0101] Table 2 Comparison of calculation results

[0102] Example 3

[0103] like Figure 2 As shown, this embodiment provides a wellhead gas injection pressure calculation device, which includes a first acquisition module 71 , a first calculation module 72 , a second calculation module 73 and a third calculation module 74 .

[0104] A first acquisition module 71 is used to acquire basic reservoir information, where the basic reservoir information includes first basic information and second basic information;

[0105] A first calculation module 72 is configured to calculate an oil recovery index and a formation gas absorption index based on the first basic information;

[0106] The second calculation module 73 is used to construct a bottom hole flow pressure model, and bring the oil production index and the formation gas absorption index into the bottom hole flow pressure model to calculate the bottom hole flow pressure of the gas injection well;

[0107] The third calculation module 74 is configured to calculate the wellhead gas injection pressure based on the bottom hole flowing pressure of the gas injection well and the second basic information.

[0108] In this embodiment, the first calculation module 72 includes a first calling unit 721 , a first calculation unit 722 and a second calculation unit 723 .

[0109] A first retrieving unit 721 is configured to retrieve the first basic information, wherein the first basic information includes daily oil production of the oil well, production pressure difference of the oil well, crude oil viscosity, crude oil volume coefficient, injected gas viscosity, gas volume coefficient, and endpoint values of the oil-gas relative permeability curve;

[0110] A first calculation unit 722 is configured to calculate the oil production index based on the daily oil production of the oil well and the production pressure difference of the oil well;

[0111] The second calculation unit 723 is configured to calculate the formation gas absorption index according to the crude oil viscosity, the crude oil volume coefficient, the injected gas viscosity, the gas volume coefficient, the endpoint value of the oil-gas relative permeability curve, and the oil recovery index.

[0112] In this embodiment, the third calculation module 74 includes a second retrieving unit 741 and a third calculation unit 742 .

[0113] The second retrieving unit 741 is used to retrieve the second basic information, where the second basic information includes the gas friction coefficient, the daily gas injection volume, the average wellbore temperature, the average gas deviation factor in the wellbore, the inner diameter of the oil pipe, the relative density of the injected gas, and the depth of the middle of the oil layer;

[0114] The third calculation unit 742 is used to bring the gas friction coefficient, daily gas injection volume, average wellbore temperature, average gas deviation factor in the wellbore, inner diameter of the oil pipe, relative density of the injected gas, middle depth of the oil layer and bottom hole flow pressure of the gas injection well into the gas vertical pipe flow energy equation to calculate the wellhead gas injection pressure.

[0115] It should be noted that, regarding the apparatus in the above embodiment, the specific manner in which each module performs operations has been described in detail in the embodiment of the method, and will not be elaborated on here.

[0116] Example 4

[0117] Corresponding to the above method embodiment, the embodiment of the present disclosure further provides a wellhead gas injection pressure calculation device. The wellhead gas injection pressure calculation device described below and the wellhead gas injection pressure calculation method described above can refer to each other.

[0118] Figure 3 FIG. 8 is a block diagram of a wellhead gas injection pressure calculation device 800 according to an exemplary embodiment. Figure 3 As shown, the electronic device 800 may include: a processor 801 , a memory 802 , and may further include one or more of a multimedia component 803 , an input / output (I / O) interface 804 , and a communication component 805 .

[0119] The processor 801 is used to control the overall operation of the electronic device 800 to complete all or part of the steps in the wellhead gas injection pressure calculation method described above. The memory 402 is used to store various types of data to support the operation of the electronic device 800. Such data may include, for example, instructions for any application or method operating on the electronic device 800, as well as application-related data, such as contact information, sent and received messages, pictures, audio, video, etc. The memory 802 can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as static random access memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic storage, flash memory, magnetic disk, or optical disk. The multimedia component 803 may include a screen and an audio component. The screen may be, for example, a touch screen, and the audio component is used to output and / or input audio signals. For example, the audio component may include a microphone for receiving external audio signals. The received audio signal may be further stored in the memory 802 or sent through the communication component 805. The audio component also includes at least one speaker for outputting audio signals. The I / O interface 804 provides an interface between the processor 801 and other interface modules. The above-mentioned other interface modules may be a keyboard, a mouse, buttons, etc. These buttons may be virtual buttons or physical buttons. The communication component 805 is used for wired or wireless communication between the electronic device 800 and other devices. Wireless communication, such as Wi-Fi, Bluetooth, near field communication (NFC), 2G, 3G or 4G, or a combination of one or more thereof, so the corresponding communication component 805 may include: a Wi-Fi module, a Bluetooth module, an NFC module.

[0120] In an exemplary embodiment, the electronic device 800 can be implemented by one or more application-specific integrated circuits (ASICs), digital signal processors (DSPs), digital signal processing devices (DSPDs), programmable logic devices (PLDs), field programmable gate arrays (FPGAs), controllers, microcontrollers, microprocessors, or other electronic components to execute the above-mentioned wellhead gas injection pressure calculation method.

[0121] In another exemplary embodiment, a computer-readable storage medium including program instructions is also provided. When executed by a processor, the program instructions implement the steps of the wellhead gas injection pressure calculation method described above. For example, the computer-readable storage medium may be the aforementioned memory 802 including the program instructions. The program instructions may be executed by the processor 801 of the electronic device 800 to implement the wellhead gas injection pressure calculation method described above.

[0122] Example 5

[0123] Corresponding to the above method embodiment, the embodiment of the present disclosure further provides a readable storage medium. The readable storage medium described below and the wellhead gas injection pressure calculation method described above can refer to each other.

[0124] A readable storage medium stores a computer program, which, when executed by a processor, implements the steps of the wellhead gas injection pressure calculation method of the above method embodiment.

[0125] The readable storage medium may specifically be any readable storage medium that can store program code, such as a USB flash drive, a mobile hard disk, a read-only memory (ROM), a random access memory (RAM), a magnetic disk, or an optical disk.

[0126] The foregoing description is merely a preferred embodiment of the present invention and is not intended to limit the present invention. Those skilled in the art will readily appreciate that various modifications and variations of the present invention are possible. Any modifications, equivalent substitutions, or improvements made within the spirit and principles of the present invention are intended to be within the scope of protection of the present invention.

Claims

1. A method for calculating wellhead gas injection pressure, characterized in that: The method comprises: Acquiring basic information of the oil reservoir, wherein the basic information of the oil reservoir includes first basic information and second basic information; Calculating the oil recovery index and the formation gas absorption index based on the first basic information; Constructing a bottom hole flow pressure model, and bringing the oil production index and the formation gas absorption index into the bottom hole flow pressure model to calculate the bottom hole flow pressure of the gas injection well; The bottom hole pressure model is Where, P wf is the bottom hole flowing pressure of the gas injection well; P r is the formation static pressure; P o is atmospheric pressure; Q g P o Daily gas injection volume under pressure; J g is the formation aspiration index; The wellhead gas injection pressure is calculated based on the bottom hole flowing pressure of the gas injection well and the second basic information.

2. The method for calculating wellhead gas injection pressure according to claim 1, characterized in that: The oil recovery index and the formation gas absorption index are calculated based on the first basic information, including: Retrieving the first basic information, wherein the first basic information includes daily oil production of the oil well, production pressure difference of the oil well, crude oil viscosity, crude oil volume coefficient, injected gas viscosity, gas volume coefficient, and endpoint values of an oil-gas relative permeability curve; Calculating the oil production index based on the daily oil production of the oil well and the production pressure difference of the oil well; The formation gas absorption index is calculated based on the crude oil viscosity, the crude oil volume coefficient, the injected gas viscosity, the gas volume coefficient, the endpoint value of the oil-gas relative permeability curve and the oil recovery index.

3. The method for calculating wellhead gas injection pressure according to claim 1, characterized in that: The calculating the wellhead gas injection pressure according to the bottom hole flowing pressure of the gas injection well and the second basic information includes: Retrieving the second basic information, the second basic information including the gas friction coefficient, the daily gas injection volume, the average wellbore temperature, the average gas deviation factor in the wellbore, the inner diameter of the oil pipe, the relative density of the injected gas, and the depth of the middle of the oil layer; The gas friction coefficient, daily gas injection volume, average wellbore temperature, average gas deviation factor in the wellbore, inner diameter of the oil pipe, relative density of the injected gas, depth of the middle oil layer and bottom hole flow pressure of the gas injection well are substituted into the gas vertical pipe flow energy equation to calculate the wellhead gas injection pressure.

4. A wellhead gas injection pressure calculation device, characterized in that: The device comprises: A first acquisition module is used to acquire basic reservoir information, where the basic reservoir information includes first basic information and second basic information; a first calculation module, configured to calculate an oil recovery index and a formation gas absorption index based on the first basic information; A second calculation module is used to construct a bottom hole flow pressure model, and bring the oil production index and the formation gas absorption index into the bottom hole flow pressure model to calculate the bottom hole flow pressure of the gas injection well; a third calculation module, configured to calculate a wellhead gas injection pressure based on the bottom hole flowing pressure of the gas injection well and the second basic information; The device is used to calculate the wellhead gas injection pressure according to the wellhead gas injection pressure calculation method according to any one of claims 1 to 3.

5. The wellhead gas injection pressure calculation device according to claim 4, characterized in that: The first calculation module includes: a first retrieving unit, configured to retrieve the first basic information, wherein the first basic information includes daily oil production of the oil well, production pressure difference of the oil well, crude oil viscosity, crude oil volume coefficient, injected gas viscosity, gas volume coefficient, and endpoint values of an oil-gas relative permeability curve; a first calculation unit, configured to calculate the oil production index according to the daily oil production of the oil well and the production pressure difference of the oil well; The second calculation unit is used to calculate the formation gas absorption index according to the crude oil viscosity, the crude oil volume coefficient, the injected gas viscosity, the gas volume coefficient, the endpoint value of the oil-gas relative permeability curve and the oil production index.

6. The wellhead gas injection pressure calculation device according to claim 4, characterized in that: The third computing module includes: a second retrieving unit, configured to retrieve the second basic information, wherein the second basic information includes a gas friction coefficient, a daily gas injection volume, an average wellbore temperature, an average gas deviation factor in the wellbore, an inner diameter of the oil pipe, a relative density of the injected gas, and a depth to the middle of the oil layer; The third calculation unit is used to bring the gas friction coefficient, daily gas injection volume, average wellbore temperature, average gas deviation factor in the wellbore, inner diameter of the oil pipe, relative density of the injected gas, middle depth of the oil layer and bottom hole flow pressure of the gas injection well into the gas vertical pipe flow energy equation to calculate the wellhead gas injection pressure.

7. A wellhead gas injection pressure calculation device, characterized in that: include: memory for storing computer programs; A processor, configured to implement the steps of the method for calculating wellhead gas injection pressure as claimed in any one of claims 1 to 3 when executing the computer program.

8. A readable storage medium, characterized in that: The readable storage medium stores a computer program, which, when executed by a processor, implements the steps of the method for calculating wellhead gas injection pressure according to any one of claims 1 to 3.

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