Method and device for calculating dynamic permeability of reservoir gas well

Abstract

The invention provides a reservoir gas well dynamic permeability calculation method and device, and relates to the technical field of oil-gas field development. The method comprises the following steps: acquiring a total stratum coefficient according to well testing data; obtaining the fluid yield, the wellbore flow pressure and the average pressure of the stratum according to the production logging; obtaining the reservoir thickness according to the logging information; and according to the total formation coefficient, the fluid yield, the wellbore flow pressure, the average pressure of the formation and the reservoir thickness, utilizing a pre-established reservoir gas well dynamic permeability model to calculate and obtain the reservoir gas well dynamic permeability. The device executes the method. According to the method and device for calculating the dynamic permeability of the reservoir gas well, the calculation accuracy of the dynamic permeability of the reservoir gas well can be improved, and the method and device have high applicability.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas field development, and particularly relates to a method and device for calculating the dynamic permeability of a reservoir gas well. Background Art

[0002] The dynamic permeability of a reservoir gas well is an important parameter for measuring the ability of porous rock to allow fluid to pass through, and is of great significance for the development and evaluation of oil and gas fields. At present, the methods for obtaining the dynamic permeability of a reservoir gas well mainly include the following several kinds:

[0003] Well testing method: By injecting or extracting fluid into the reservoir and observing the change of fluid pressure with time, the permeability of the reservoir gas well can be deduced. This method can obtain the permeability on a large scale of the reservoir and can better represent the true permeability of the reservoir. Well testing methods mainly include pressure build-up well testing, pressure drawdown well testing, interference well testing, etc. Among them, long-term pressure drawdown and pressure build-up well testing can obtain the area affected by pressure, and the average permeability of a block can be calculated by well testing means, which can better reflect the true permeability of the formation in this block. However, affected by reservoir heterogeneity and fluid properties, there may be certain errors in the interpretation results.

[0004] Laboratory experiment method: It mainly obtains permeability data by means of laboratory physical property analysis of cores. By sampling the cores and then conducting physical property experiments, such as porosity measurement, permeability measurement, etc. Permeability measurement usually adopts the steady-state method or the transient method. Among them, the steady-state method calculates the permeability by measuring the pressure difference and flow rate at both ends of the core, and the transient method calculates the permeability by observing the change of pressure with time. It is also possible to combine nuclear magnetic T2 experiment and mercury injection experiment, etc., to obtain the nuclear magnetic T2 spectrum and mercury injection experiment data of the core, and then analyze the permeability. Since in the actual coring process, cores are only taken from the key horizons of key wells in the oilfield, the relationships established based on the relatively limited core phase permeability tests of some reservoirs cannot be applicable to all reservoirs, and these relationships are subject to certain limitations in practical applications. Moreover, there are differences between laboratory experimental conditions and actual underground conditions, and the experimental results may be affected by factors such as experimental conditions, core sampling, and measurement errors.

[0005] Empirical formula and model method: It mainly establishes an empirical formula or model based on the statistical relationship between logging parameters and permeability to predict permeability. However, the accuracy and applicability of the model directly affect the calculation result of permeability. For complex reservoirs, a single model may be difficult to accurately obtain the permeability. Summary of the Invention

[0006] Aiming at the problems in the prior art, the embodiments of the present invention provide a method and device for calculating the dynamic permeability of a reservoir gas well, which can at least partially solve the problems existing in the prior art.

[0007] On the one hand, the present invention provides a method for calculating the dynamic permeability of a reservoir gas well, comprising:

[0008] Obtaining the total formation coefficient according to well test data; obtaining the fluid production, wellbore flowing pressure and average formation pressure according to production logging; obtaining the reservoir thickness according to logging data;

[0009] Calculating the dynamic permeability of the reservoir gas well based on the total formation coefficient, the fluid production, the wellbore flowing pressure, the average formation pressure and the reservoir thickness, and using a pre-established dynamic permeability model of the reservoir gas well;

[0010] Wherein, the expression of the dynamic permeability model of the reservoir gas well is as follows:

[0011]

[0012] Wherein, K i is the dynamic permeability of the reservoir gas well of the i-th layer, K'h is the total formation coefficient, q i is the fluid production, P wfi is the wellbore flowing pressure, is the average formation pressure, h i is the reservoir thickness, and n is the total number of layers included in the reservoir gas well.

[0013] Wherein, the method for calculating the dynamic permeability of the reservoir gas well further comprises:

[0014] Calculating the dynamic permeability of the reservoir gas well according to the following expression:

[0015] K i = a i K

[0016] Wherein, a i is the contribution weight of the permeability of the i-th layer to the total permeability, and K is the theoretical value of the total dynamic permeability of the reservoir gas well.

[0017] Wherein, a is calculated according to the following expression i :

[0018]

[0019] Wherein, after the step of calculating the dynamic permeability of the reservoir gas well, the method for calculating the dynamic permeability of the reservoir gas well further comprises:

[0020] Monitoring the dynamic permeability of the reservoir gas well, and predicting the exploitation dynamics of the gas reservoir according to the change trend of the dynamic permeability of the reservoir gas well.

[0021] Wherein, after the step of calculating the dynamic permeability of the reservoir gas well, the method for calculating the dynamic permeability of the reservoir gas well further includes:

[0022] Monitoring the dynamic permeability of the reservoir gas well, and predicting the remaining reserves of the gas reservoir according to the change trend of the dynamic permeability of the reservoir gas well.

[0023] Wherein, before the steps of obtaining the total formation coefficient according to well test data; obtaining the fluid production, wellbore flowing pressure and average pressure of the formation according to production logging; and obtaining the reservoir thickness according to logging data, the method for calculating the dynamic permeability of the reservoir gas well further includes:

[0024] Using geophysical methods to obtain the well test data and the logging data.

[0025] On the one hand, the present invention provides a device for calculating the dynamic permeability of a reservoir gas well, including:

[0026] An acquisition unit, configured to obtain the total formation coefficient according to well test data; obtain the fluid production, wellbore flowing pressure and average pressure of the formation according to production logging; and obtain the reservoir thickness according to logging data;

[0027] A calculation unit, configured to calculate the dynamic permeability of the reservoir gas well according to the total formation coefficient, the fluid production, the wellbore flowing pressure, the average pressure of the formation and the reservoir thickness, and by using a pre-established dynamic permeability model of the reservoir gas well;

[0028] Wherein, the expression of the dynamic permeability model of the reservoir gas well is as follows:

[0029]

[0030] Wherein, K i is the dynamic permeability of the reservoir gas well of the i-th layer, K'h is the total formation coefficient, q i is the fluid production, P wfi is the wellbore flowing pressure, is the average pressure of the formation, h i is the reservoir thickness, and n is the total number of layers included in the reservoir gas well.

[0031] On the other hand, an embodiment of the present invention provides a computer device, including a memory, a processor, and a computer program stored on the memory and executable on the processor. When the processor executes the computer program, the following method is implemented:

[0032] Obtaining the total formation coefficient according to well test data; obtaining the fluid production, wellbore flowing pressure and average pressure of the formation according to production logging; and obtaining the reservoir thickness according to logging data;

[0033] Based on the total formation coefficient, the fluid production rate, the wellbore flowing pressure, the average pressure of the formation, and the reservoir thickness, and using a pre-established dynamic permeability model for reservoir gas wells, the dynamic permeability of the reservoir gas wells is calculated;

[0034] Among them, the expression of the dynamic permeability model for reservoir gas wells is as follows:

[0035]

[0036] Among them, K i is the dynamic permeability of the reservoir gas well in the i-th layer, K'h is the total formation coefficient, q i is the fluid production rate, P wfi is the wellbore flowing pressure, is the average pressure of the formation, h i is the reservoir thickness, and n is the total number of layers included in the reservoir gas well.

[0037] An embodiment of the present invention provides a computer-readable storage medium, including:

[0038] The computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, the following method is implemented:

[0039] Obtain the total formation coefficient according to well test data; obtain the fluid production rate, wellbore flowing pressure, and average pressure of the formation according to production logging; obtain the reservoir thickness according to logging data;

[0040] Based on the total formation coefficient, the fluid production rate, the wellbore flowing pressure, the average pressure of the formation, and the reservoir thickness, and using a pre-established dynamic permeability model for reservoir gas wells, the dynamic permeability of the reservoir gas wells is calculated;

[0041] Among them, the expression of the dynamic permeability model for reservoir gas wells is as follows:

[0042]

[0043] Among them, K i is the dynamic permeability of the reservoir gas well in the i-th layer, K'h is the total formation coefficient, q i is the fluid production rate, P wfi is the wellbore flowing pressure, is the average pressure of the formation, h i is the reservoir thickness, and n is the total number of layers included in the reservoir gas well.

[0044] An embodiment of the present invention further provides a computer program product, the computer program product includes a computer program, and when the computer program is executed by a processor, the following method is implemented:

[0045] Obtain the total formation coefficient according to well test data; obtain the fluid production rate, wellbore flowing pressure, and average formation pressure according to production logging; obtain the reservoir thickness according to logging data;

[0046] According to the total formation coefficient, the fluid production rate, the wellbore flowing pressure, the average formation pressure, and the reservoir thickness, and by using a pre-established dynamic permeability model of the reservoir gas well, calculate the dynamic permeability of the reservoir gas well;

[0047] Among them, the expression of the dynamic permeability model of the reservoir gas well is as follows:

[0048]

[0049] Among them, K i is the dynamic permeability of the reservoir gas well of the i-th layer, K'h is the total formation coefficient, q i is the fluid production rate, P wfi is the wellbore flowing pressure, is the average formation pressure, h i is the reservoir thickness, and n is the total number of layers included in the reservoir gas well.

[0050] The method and device for calculating the dynamic permeability of a reservoir gas well provided by the embodiments of the present invention obtain the total formation coefficient according to well test data; obtain the fluid production rate, wellbore flowing pressure, and average formation pressure according to production logging; obtain the reservoir thickness according to logging data; according to the total formation coefficient, the fluid production rate, the wellbore flowing pressure, the average formation pressure, and the reservoir thickness, and by using a pre-established dynamic permeability model of the reservoir gas well, calculate the dynamic permeability of the reservoir gas well, which can improve the calculation accuracy of the dynamic permeability of the reservoir gas well and has strong applicability. Description of the Drawings

[0051] In order to more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the following will briefly introduce the drawings required for use in the description of the embodiments or the prior art. Obviously, the following drawings are only some embodiments of the present invention. For those of ordinary skill in the art, without creative efforts, other drawings can also be obtained according to these drawings. In the drawings:

[0052] Figure 1 is a schematic flow chart of a method for calculating the dynamic permeability of a reservoir gas well provided by an embodiment of the present invention.

[0053] Figure 2 is a schematic structural diagram of a device for calculating the dynamic permeability of a reservoir gas well provided by an embodiment of the present invention.

[0054] Figure 3Schematic diagram of the physical structure of the computer device provided by an embodiment of the present invention. Detailed implementation manners

[0055] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer and more understandable, the following further describes the embodiments of the present invention in detail with reference to the accompanying drawings. Herein, the illustrative embodiments of the present invention and their descriptions are used to explain the present invention, but not to limit the present invention. It should be noted that, without conflict, the embodiments in the present application and the features in the embodiments may be arbitrarily combined with each other.

[0056] Figure 1 is a flowchart of a method for calculating the dynamic permeability of a reservoir gas well provided by an embodiment of the present invention. As Figure 1 shown, the method for calculating the dynamic permeability of a reservoir gas well provided by the embodiment of the present invention includes:

[0057] Step S1: Obtain the total formation coefficient according to well test data; obtain the fluid production, wellbore flowing pressure, and average formation pressure according to production logging; obtain the reservoir thickness according to logging data.

[0058] Step S2: Calculate the dynamic permeability of the reservoir gas well according to the total formation coefficient, the fluid production, the wellbore flowing pressure, the average formation pressure, and the reservoir thickness, and by using a pre-established dynamic permeability model of the reservoir gas well;

[0059] wherein, the expression of the dynamic permeability model of the reservoir gas well is as follows:

[0060]

[0061] wherein, K i is the dynamic permeability of the i-th layer of the reservoir gas well, K'h is the total formation coefficient, q i is the fluid production, P wfi is the wellbore flowing pressure, is the average formation pressure, h i is the reservoir thickness, and n is the total number of layers included in the reservoir gas well.

[0062] In the above step S1, the device obtains the total formation coefficient according to well test data; obtains the fluid production, wellbore flowing pressure, and average formation pressure according to production logging; obtains the reservoir thickness according to logging data. The device may be a computer device that executes this method, such as a server.

[0063] The obtaining of the total formation coefficient according to well test data is described as follows:

[0064] The obtaining of the total formation coefficient according to well test data can be realized by establishing and solving a binomial equation with the formation coefficient as the unknown.

[0065] The total formation coefficient is the product of the total reservoir thickness h (m) and the actual value of the total reservoir gas well dynamic permeability K′ (mD). In gas wells, the total formation coefficient can be determined by the binomial well test open flow method. This method is based on the gas seepage mechanics theory and the general formula of the binomial production capacity equation, and establishes a binomial equation with "K′h" as the unknown quantity. For this equation, according to the known parameters, the parameters calculated by the gas reservoir engineering, the relevant well test interpretation parameters, combined with the production dynamic data, the "K′h" value, that is, the total formation coefficient, can be obtained by solving it.

[0066] In addition, well test data can also be used to obtain other formation parameters, such as original formation pressure, effective permeability, flow coefficient, skin coefficient, etc., and can determine sandstone connectivity, reservoir boundary type and distance, and evaluate reservoir energy, reservoir fractures, heterogeneity, reservoir seepage characteristics and fracturing effect. These parameters and evaluations are of great significance for exploration and development.

[0067] In summary, the method of obtaining the total formation coefficient based on well test data mainly includes establishing and solving the binomial equation with the formation coefficient as the unknown quantity, and using methods such as history matching to inversely obtain the formation parameters.

[0068] The binomial well test method of gas well formation coefficient is a method to solve the formation coefficient, open flow rate and other parameters of the gas well by processing the gas well system test data with the binomial equation.

[0069] In the binomial well test method, the production of each working system and the corresponding stable bottom hole pressure data are usually used to establish a set of equations and eliminate the parameter formation pressure. Through graphical methods or direct solution of the equations, key parameters such as the production capacity equation coefficient, current formation pressure, and open flow can be obtained. This method avoids the errors and inconveniences caused by long-term shut-in testing of formation pressure in low-permeability gas wells, which is conducive to reducing testing costs, accelerating work progress, and improving the quality of results.

[0070] In addition, there is a method of processing system well test data by deriving and applying the binomial derivative equation. This method can also directly calculate the formation pressure and the absolute unobstructed flow rate of the gas well based on the relationship between the flowing pressure and the production.

[0071] It is worth noting that when using the binomial capacity evaluation method, it is necessary to correctly understand its applicable conditions and select the appropriate analysis method according to the actual situation to ensure the accuracy of the results. For example, under low pressure conditions, the higher the temperature, the smaller the relative error of the pressure square analysis method; while under high pressure conditions, the higher the temperature, the greater the relative error of the pressure analysis method. Therefore, in practical applications, it is necessary to select according to the specific conditions of the gas well.

[0072] Generally speaking, the binomial well test method is an effective method for determining parameters such as the formation coefficient of gas wells and has broad application prospects.

[0073] The acquisition of fluid production according to production logging is explained as follows:

[0074] The main method for obtaining fluid production according to production logging is to use a flowmeter. Commonly used ones are turbine flowmeters and mass flowmeters.

[0075] During the process of oil extraction, in order to know the production of each oil layer, it is necessary to use a flowmeter for measurement. Flow logging is to lower the flowmeter down the oil well to the location of the oil layer for measurement. Due to the harsh environment thousands of meters deep in the oil well, downhole flowmeters are used. It consists of a flow sensor and complex electronic circuits. During logging, it is automatically controlled by a computer system, and the measurement signal is transmitted to the ground for recording and display through a cable.

[0076] Among them, the turbine flowmeter is a velocity-type flowmeter, and its measurement principle is based on the fluid momentum theorem. When the fluid passes through the flowmeter, it will push the turbine blades to rotate, and the rotation speed of the blades is proportional to the flow velocity of the fluid. By measuring the turbine rotation speed, the volume flow rate of the fluid can be calculated.

[0077] In addition, the mass flowmeter is also a commonly used device. It directly measures the mass flow rate of the fluid. Common types include Coriolis mass flowmeters. Its measurement principle is based on the Coriolis force effect. When the fluid flows through the vibrating measuring tube, a Coriolis force will be generated, causing the measuring tube to twist. By measuring the twist angle of the measuring tube, the mass flow rate of the fluid can be calculated.

[0078] Whether it is a turbine flowmeter or a mass flowmeter, their measurement accuracy depends on the accuracy of the flowmeter coefficient, which will be affected by factors such as temperature, pressure, and fluid density. Therefore, it is necessary to calibrate the flowmeter regularly to ensure the accuracy of the measurement results.

[0079] To sum up, through flow logging and using a suitable flowmeter, the fluid production can be accurately obtained, providing important data support for oil extraction.

[0080] Although the above methods are mainly for gas wells, similar methods can also be applied to oil wells to obtain formation parameters by well test data. For example, the method of history matching can be used to interpret oil well test data and determine formation parameters. Treat the formation parameters to be determined as control variables. When the value of the formation parameters obtained by automatic adjustment on the computer model can make the theoretical curve and the measured curve achieve the best match, the value of the control variable at this time is considered to be the actual parameter value of the formation.

[0081] The acquisition of wellbore flow pressure according to production logging is explained as follows:

[0082] Methods for obtaining wellbore flow pressure include field measurement methods and calculation methods. However, production logging itself does not directly provide information on wellbore flow pressure. Production logging is mainly used to evaluate the petrophysical properties of the formation, such as porosity, permeability, etc. However, by combining production logging data with other production data, the wellbore flow pressure can be indirectly deduced. The following are the specific methods and steps:

[0083] Field measurement methods:

[0084] Lowering a pressure gauge for measurement: This is the most direct and accurate method. Lower a pressure gauge into the wellbore to measure the pressure profile of the wellbore, thereby obtaining the wellbore flow pressure.

[0085] Measuring the bottom-hole pressure with a bottom-hole pressure gauge: In gas wells, a bottom-hole pressure gauge can be used to measure the bottom-hole flow pressure. For high-sulfur gas wells, due to their corrosiveness, pressure gauges with special designs are required.

[0086] Calculation methods:

[0087] Calculating based on production data: Based on production data, physical property parameters of the produced fluid, etc., calculate the wellbore pressure through a pressure calculation model. This method does not need to affect the normal production operation of the gas well, and the bottom-hole pressure can be calculated only through relevant parameters.

[0088] Using the Cullender-Smith method and the methods of average temperature and compressibility factor: This is a commonly used method for calculating the bottom-hole pressure of gas wells. For high-sulfur gas wells, their particularities need to be considered, the deviation factor needs to be corrected, and a new multi-node calculation method for deep wells is used to deduce the bottom-hole flowing pressure.

[0089] Regarding the average pressure of the formation obtained from production logging, the following explanations are provided:

[0090] Calculating the average formation pressure:

[0091] The average formation pressure is obtained by weighted averaging according to the pore volume. If the pressure distribution in the formation during oil well production is known, assuming the formation pressure at any radial distance r is p, it can be calculated through integration.

[0092] Another calculation method is based on the material balance equation during oil well production and the radial seepage equation of the fluid in the formation, which is applicable to the case of pseudo-steady flow in a circular closed formation.

[0093] Data interpretation and application:

[0094] By analyzing logging data, oil, gas, and water layers can be interpreted and evaluated, and the porosity, permeability, and oil (gas) saturation of the hydrocarbon-bearing rock series can be calculated.

[0095] The calculation of the average formation pressure is the application of well test interpretation results. It can accurately reflect the current energy status of the oil reservoir and provide a basis for the rational development of oil and gas and scientific drilling.

[0096] The method of obtaining the reservoir thickness from well logging data is described as follows:

[0097] The methods of obtaining the reservoir thickness from well logging data mainly include direct division and calculation using well logging curves.

[0098] Specifically, it can be carried out through the following steps:

[0099] Select appropriate well logging instruments: According to the conductivity, radioactivity and other characteristics of the reservoir, select suitable well logging instruments, such as resistivity logging instruments, induction logging instruments, natural gamma spectrometers, etc.

[0100] Conduct well logging data acquisition: Use well logging instruments to acquire data in the oil well, including steps such as sampling by the well logging instrument probe, signal amplification, and data storage and transmission by the recording instrument.

[0101] Analyze well logging curves: According to the acquired well logging data, draw corresponding well logging curves, such as apparent resistivity curves, natural gamma curves, etc. These curves can reflect the electrical properties, radioactivity and other characteristics of the reservoir, so as to be used for dividing the reservoir, effective layers and interlayers, and determining the lower limit of the effective thickness.

[0102] Calculate the reservoir thickness: Use the characteristic points on the well logging curve, such as the depths corresponding to the top and bottom boundaries of the formation, to calculate the reservoir thickness. For high resistivity formations, the apparent resistivity curve shows a minimum value at the top interface of the formation and a maximum value at the bottom interface of the formation. According to the depth difference corresponding to these two characteristic values, the reservoir thickness can be obtained.

[0103] In addition, geological data, well testing data, drilling and core data, etc. can be combined to comprehensively analyze the well logging data to improve the accuracy of reservoir thickness calculation.

[0104] Before the steps of obtaining the total formation coefficient according to well test data; obtaining fluid production, wellbore flow pressure and average formation pressure of the formation according to production logging; obtaining reservoir thickness according to well logging data, the dynamic permeability calculation method of the reservoir gas well further includes:

[0105] Obtain the well test data and the well logging data by geophysical methods.

[0106] The well test data obtained by geophysical methods is described as follows:

[0107] Well test data is obtained based on geophysical methods, mainly through geophysical logging technology. Geophysical logging, abbreviated as logging, is an applied technical discipline that uses geophysical methods to measure various physical information of rock formations in wells, study the drilling geological profiles of oil and gas fields, coal fields, etc., and solve certain underground geological, production, and drilling technical problems.

[0108] Specifically, logging is a method of measuring geophysical parameters such as the conductivity, acoustic properties, radioactivity, and electrochemical properties of rock formations along the drilling profile through special downhole instruments. These parameters include but are not limited to resistivity, acoustic velocity, rock density, and ray capture and emission capabilities. There are many logging methods, and acoustic, electrical, and radioactive methods are the most basic ones. Each logging method can only indirectly and conditionally reflect a certain aspect of the characteristics of rock formations. Therefore, to comprehensively understand the underground geological situation and discover and evaluate oil and gas layers, multiple logging methods should be applied comprehensively.

[0109] In oil exploration and development, logging is an essential link. After the drilling reaches the designed well depth, logging is required to obtain various petroleum geological and engineering technical data as the original data for well completion and oilfield development. This kind of logging is customarily called open-hole logging. And the series of logging carried out after the casing is run in the oil well is customarily called production logging or development logging.

[0110] The well test data obtained based on geophysical methods is described as follows:

[0111] In actual operation, logging is usually completed by a logging truck or logging equipment. These equipments contain special downhole instruments that can measure various physical parameters of rock formations along the drilling profile. Logging data will be collected and recorded, and then processed and interpreted to obtain detailed information about the underground geological situation.

[0112] In the above step S2, the device calculates the dynamic permeability of the reservoir gas well according to the total formation coefficient, the fluid production rate, the wellbore flow pressure, the average pressure of the formation, and the reservoir thickness, and by using a pre-established dynamic permeability model of the reservoir gas well.

[0113] Among them, the expression of the dynamic permeability model of the reservoir gas well is as follows:

[0114]

[0115] Among them, K i is the dynamic permeability of the reservoir gas well of the i-th layer, K'h is the total formation coefficient, q i is the fluid production rate, P wfi is the wellbore flow pressure, is the average pressure of the formation, h iwhere \(h\) is the reservoir thickness and \(n\) is the total number of layers in the reservoir gas well. Each data can be substituted into the expression of the above-mentioned dynamic permeability model of the reservoir gas well, so as to calculate the dynamic permeability of the \(i\)-th layer of the reservoir gas well.

[0116] That is, under the condition of lacking core data and single-layer well testing, the permeability of the reservoir can be directly calculated by using the well testing data and logging data obtained by geophysical methods.

[0117] The establishment of the dynamic permeability model of the reservoir gas well is described as follows:

[0118] Analyze the production profile data of production logging and the injection profile data of injection wells, sort out the flowing pressure, flow rate, water production, gas production, injection volume and other data of each layer, as well as the average permeability data of the reservoir from well testing. Then, starting from the single-phase and two-phase seepage theory, establish an evaluation model for determining the reservoir permeability of a single well using the above data.

[0119] The above-mentioned method for calculating the dynamic permeability of a reservoir gas well further includes:

[0120] The dynamic permeability of the reservoir gas well is calculated according to the following expression:

[0121] \(K\) i \(= a\) i \(K\)

[0122] where \(a\) i is the contribution weight of the permeability of the \(i\)-th layer to the total permeability, and \(K\) is the theoretical value of the dynamic permeability of the total reservoir gas well.

[0123] \(a\) is calculated according to the following expression i :

[0124]

[0125] The derivation process of the expression of the dynamic permeability model of the reservoir gas well is described as follows:

[0126] The flow of reservoir fluid towards the well refers to the flow of gas or other media from the formation to the production well bottom along the seepage channel. The flow law satisfies Darcy's law. According to Darcy's law and the radial pressure diffusion equation, for a well at the center of a circular geological structure, when the pressure at the supply edge remains unchanged, its production formula is expressed as:

[0127]

[0128] In the formula, \(q\) is the fluid production rate, \(m\) 3 / s; \(K\) is the theoretical value of the dynamic permeability of the reservoir gas well, \(m\) 2 ; \(B\) is the fluid volume coefficient; \(h\) is the total reservoir thickness, \(m\); \(\mu\) is the fluid viscosity, Pa·s; \(P\) e is the gas reservoir boundary pressure, Pa, \(P\) wfis the flowing pressure in the wellbore, Pa; r e is the radius of the gas reservoir edge, m; r w is the wellbore radius, m.

[0129] It shows that the fluid production rate q and the pressure (P e -P wf ) are linearly related. The theoretical value of the dynamic permeability K of the reservoir gas well, the total reservoir thickness h, the fluid viscosity μ, the wellbore radius r w , and the radius of the gas reservoir edge r e are all factors affecting the seepage resistance.

[0130] From the logarithmic relationship of the formation pressure distribution, it is known that most of the pressure drop occurs near the well bottom. The average pressure of the formation can be obtained by using the method of curved surface weighted average The formation production formula represented by:

[0131]

[0132] After arrangement, we get:

[0133]

[0134] It can be seen from the above formula that when the fluid viscosity μ, the fluid volume coefficient B, the wellbore radius r w , and the radius of the gas reservoir edge r e are all constant, the gas (water) production per unit thickness can reflect the permeability of the reservoir.

[0135] The evaluation method mainly uses well test and production logging data, combines with the radial flow equation, and obtains a more accurate layered permeability, that is, dynamic permeability, through multiple iterations. It can be set that:

[0136]

[0137] It can be seen from this formula that when r e , r w , μ, and B are constant, A is proportional to K. In the coordinate graph, it is a straight line. At this time, there is:

[0138]

[0139] Assume that a well includes n reservoirs, the reservoir thickness of the i-th reservoir is h i , the flowing pressure in the wellbore is P wfi , and the fluid production rate of a single layer is q i , then there is:

[0140]

[0141] The production per unit layer thickness, the pressure difference value are related to the reservoir permeability and can be predicted accordingly.

[0142] When the average permeability of multiple layers is obtained through multi-layer well testing, the contribution of the single-layer permeability to the overall permeability can be obtained by combining the liquid production of each single layer and the difference between the flowing pressure and the formation average pressure in the production logging data. The contribution weight of the permeability of the i-th layer to the total permeability can be expressed as:

[0143]

[0144] The dynamic permeability of the gas well in the i-th layer of the reservoir can be expressed as:

[0145]

[0146] Since the total formation coefficient K'h is equal to the sum of the sub-formation coefficients, that is:

[0147] ∑K i h i = K'h

[0148] Then there is:

[0149]

[0150] K' is the actual value of the dynamic permeability of the total reservoir gas well. The dynamic permeability of the gas well in the i-th layer of the reservoir can be expressed as:

[0151]

[0152] In the formula, the total formation coefficient K'h is obtained from well testing data; the fluid production, wellbore flowing pressure, and average pressure of the formation are obtained from production logging; h i is obtained from logging data. Thus, in the absence of core data and single-layer well testing, the permeability of the reservoir can be directly calculated using well testing data, production logging, and logging data obtained by geophysical methods. The processing method is as follows: First, analyze the production profile data of production logging and the injection profile data of injection wells, and sort out the flowing pressure, flow rate, water production, gas production, injection volume, etc. of each layer and the average permeability data of the reservoir in well testing. Then, starting from the single-phase two-phase seepage theory, establish a dynamic permeability model of the gas well in the reservoir for a single well using the above data.

[0153] After the step of calculating the dynamic permeability of the reservoir gas well, the method for calculating the dynamic permeability of the reservoir gas well further includes:

[0154] Monitoring the dynamic permeability of the reservoir gas well, and predicting the exploitation dynamics of the gas reservoir according to the change trend of the dynamic permeability of the reservoir gas well.

[0155] The prediction of the exploitation dynamics of the gas reservoir according to the change trend of the dynamic permeability of the reservoir gas well is described as follows:

[0156] Predicting the production dynamics of a gas reservoir based on the changing trend of the dynamic permeability of reservoir gas wells can be achieved by analyzing the main influencing factors of permeability change and their action mechanisms, combined with mathematical models and numerical simulation methods.

[0157] During the process of coalbed methane production, reservoir permeability is an important factor in measuring whether coalbed methane can be produced and the production quality. The dynamic permeability changes dynamically with the change of the reservoir environment, and these changes are jointly affected by various geological effects and engineering factors. For example, geological effects such as effective stress, matrix shrinkage, and gas slippage will have a significant impact on the permeability of coal reservoirs. Therefore, to accurately predict the production dynamics of a gas reservoir, it is necessary to comprehensively consider the combined effects of these factors on permeability change.

[0158] Specifically, the prediction can be carried out through the following steps:

[0159] Collect and analyze data:

[0160] Collect production data such as permeability, pressure, and production of reservoir gas wells.

[0161] Analyze the changing trends of these data, especially the changing rules of permeability.

[0162] Establish a mathematical model:

[0163] Based on production data, deduce a mathematical model that reflects the change of coal reservoir permeability. These models can consider the influence of geological effects such as effective stress, matrix shrinkage, and gas slippage.

[0164] Verify the accuracy of the model through laboratory research and field data.

[0165] Numerical simulation:

[0166] Adopt numerical simulation methods, such as numerical simulation software, to simulate and predict the production dynamics of the gas reservoir.

[0167] During the simulation process, input the changing trends of parameters such as permeability and pressure to reflect the dynamic change of reservoir permeability.

[0168] Result analysis and optimization:

[0169] According to the numerical simulation results, analyze the production dynamics of the gas reservoir, including production, pressure change, etc.

[0170] According to the analysis results, optimize the production strategy, such as adjusting the drainage rate, controlling the reservoir pressure, etc., to achieve high and stable production of coalbed methane wells.

[0171] In addition, the variation law of the relative permeability of coal reservoirs can be studied to further guide the prediction of the production dynamics of gas reservoirs. For example, a dynamic model of the change in the relative permeability of coal reservoirs can be established to reveal the coupling relationship between the stress-strain of coal and the change in relative permeability, as well as the control effect of the material composition and pore-fracture development on the change in relative permeability, etc.

[0172] After the step of calculating the dynamic permeability of the reservoir gas well, the method for calculating the dynamic permeability of the reservoir gas well further includes:

[0173] Monitoring the dynamic permeability of the reservoir gas well and predicting the remaining reserves of the gas reservoir according to the change trend of the dynamic permeability of the reservoir gas well.

[0174] The prediction of the remaining reserves of the gas reservoir according to the change trend of the dynamic permeability of the reservoir gas well is described as follows:

[0175] Predicting the remaining reserves of the gas reservoir according to the change trend of the dynamic permeability of the reservoir gas well can be achieved by analyzing the relationship between the change in permeability and the reserves and combining the corresponding prediction methods.

[0176] First of all, it is necessary to clarify that the dynamic permeability of the reservoir gas well changes with factors such as production time and reservoir pressure. This change will directly affect the gas well production and recovery efficiency. Therefore, by monitoring and analyzing the permeability data during the gas well production process, the change trend of permeability can be obtained.

[0177] Next, based on the change trend of permeability, the relationship between it and the remaining reserves of the gas reservoir can be further analyzed. Generally speaking, an increase in permeability may mean that more gas in the reservoir can be produced, while a decrease in permeability may indicate that the production potential of the reservoir is gradually decreasing. By establishing a mathematical model or empirical formula between permeability and remaining reserves, the remaining reserves of the gas reservoir can be preliminarily predicted.

[0178] In addition, other prediction methods can be combined, such as the material balance method, pressure build-up well test method, typical curve analysis method, etc., to comprehensively evaluate the remaining reserves of the gas reservoir. These methods have their own advantages and disadvantages and are applicable to different gas reservoir types and production conditions. Therefore, when selecting a prediction method, it is necessary to consider comprehensively according to the actual situation.

[0179] The calculation of dynamic permeability can reflect the flow state of the fluid inside the gas reservoir. By long-term monitoring and analysis of the change trend of dynamic permeability, the production dynamics and remaining reserves of the gas reservoir can be predicted. This is of great significance for the development planning and production management of oil and gas fields, helping to formulate a reasonable production plan and ensure the sustainable utilization of oil and gas resources.

[0180] Combined with a specific embodiment, the method for calculating the dynamic permeability of the reservoir gas well provided by the embodiment of the present invention is described as follows:

[0181] Well K is a production well. In the absence of core data and single-layer well test data, the dynamic permeability of each producing layer is estimated using the production logging data of the oilfield. The average permeability obtained from the well test is 2.77 mD. There are 6 producing layers in the section from 2824 m to 2920 m. The depth of producing layer 1 is from 2824 m to 2830 m, and the flowing pressure is 17.62 MPa; the depth of producing layer 2 is from 2830 m to 2847.5 m, and the flowing pressure is 17.65 MPa; the depth of producing layer 3 is from 2847.5 m to 2852.5 m, and the flowing pressure is 17.73 MPa; the depth of producing layer 4 is from 2852.5 m to 2862 m, and the flowing pressure is 17.82 MPa; the depth of producing layer 5 is from 2862 m to 2880 m, and the flowing pressure is 17.85 MPa; the depth of producing layer 6 is from 2880 m to 2920 m, and the flowing pressure is 17.91 MPa.

[0182] According to the development series, the well is divided into four major layers in combination with the original permeability data:

[0183] The first major layer: layer 1, layer 2;

[0184] The second major layer: layer 3;

[0185] The third major layer: layer 4, layer 5;

[0186] The fourth major layer: layer 6;

[0187] Process the data according to the above implementation process to obtain the final interpretation result:

[0188] The permeability of producing layer 1 is 1.17 mD, the permeability of producing layer 2 is 0.63 mD, and the permeability of the major layer is 0.89 mD;

[0189] The permeability of producing layer 3 is 6.36 mD, and the permeability of the major layer is 6.36 mD;

[0190] The permeability of producing layer 4 is 5.61 mD, the permeability of producing layer 5 is 2.77 mD, and the permeability of the major layer is 3.75 mD;

[0191] The permeability of producing layer 6 is 0.41 mD, and the permeability of the major layer is 0.41 mD;

[0192] The calculation results well reflect the fluid properties of each sub-layer. In the absence of core data and single-layer well test data, the dynamic permeability of each producing layer can be estimated using the production logging data of the oilfield, and these dynamic permeabilities can better reflect the liquid production properties of each sub-layer.

[0193] The reservoir space combination type of Gas Field B is fracture-porous type. The reservoir has obvious layered characteristics, with serious plane and vertical heterogeneity. All the well tests carried out during production logging are multi-layer well tests. Thus, it is impossible to estimate the dynamic permeability of a single layer only relying on well test data. Using the method described above, the effective permeability of each small layer can be calculated simultaneously. The verification is shown in Table 1 as follows:

[0194] Table 1

[0195]

[0196]

[0197] It can be seen from the comparison of the three permeabilities that neither the average permeability interpreted by well test nor the permeability interpreted by logging can reflect the dynamic conditions of each producing layer. Only the permeability interpreted by well test and production logging can more truly reflect the liquid production characteristics of the reservoir. In the case of lacking core data and single-layer well test data, the dynamic permeability of each producing layer can be estimated by combining the well test data of multi-layer combined test and production logging data. These dynamic permeabilities can better reflect the properties of each small layer than the permeability interpreted by logging and the average permeability interpreted by well test. The example proves that this method has good application value in practice.

[0198] For the method for calculating the dynamic permeability of a gas well in a reservoir provided by the embodiment of the present invention, in the case of lacking core data and single-layer well test data, the present invention uses the production logging data of the oilfield, combines the seepage principle and geophysical logging method, and successfully estimates the dynamic permeability of each producing layer. This estimation method can better reflect the fluid properties and liquid production characteristics of each small layer, and improves the accuracy and reliability of permeability calculation. Compared with the conventional well test method, the present invention avoids long-term pressure drawdown and pressure build-up well tests, reduces the possibility of production decline or even shutdown of low-production wells. At the same time, by simplifying the calculation process, the cost is reduced and the work efficiency is improved. By long-term monitoring and analyzing the change trend of the dynamic permeability, the exploitation dynamics and remaining reserves of the gas reservoir can be predicted. This helps to formulate a reasonable exploitation plan, optimize production management, and improve the development efficiency and economic benefits of oil and gas fields. The present invention is applicable to the calculation of the dynamic permeability of gas wells in complex reservoirs and ultra-deep fracture reservoirs, especially in the case of complex reservoir heterogeneity and fluid properties, and can provide more accurate and reliable permeability data. It can truly reflect the liquid production characteristics of the reservoir and has good application value.

[0199] The method for calculating the dynamic permeability of a reservoir gas well provided by the embodiment of the present invention obtains the total formation coefficient according to well test data; obtains the fluid production, wellbore flowing pressure and average formation pressure according to production logging; obtains the reservoir thickness according to logging data; and calculates the dynamic permeability of the reservoir gas well by using the pre-established dynamic permeability model of the reservoir gas well, which can improve the calculation accuracy of the dynamic permeability of the reservoir gas well and has strong applicability.

[0200] Further, the method for calculating the dynamic permeability of the reservoir gas well further includes:

[0201] The dynamic permeability of the reservoir gas well is calculated according to the following expression:

[0202] K i = a i K

[0203] where a i is the contribution weight of the permeability of the i-th layer to the total permeability, and K is the theoretical value of the total dynamic permeability of the reservoir gas well. It can be described with reference to the above embodiments and will not be elaborated here.

[0204] Further, a is calculated according to the following expression i :

[0205]

[0206] It can be described with reference to the above embodiments and will not be elaborated here.

[0207] Further, after the step of calculating the dynamic permeability of the reservoir gas well, the method for calculating the dynamic permeability of the reservoir gas well further includes:

[0208] Monitoring the dynamic permeability of the reservoir gas well, and predicting the exploitation dynamics of the gas reservoir according to the change trend of the dynamic permeability of the reservoir gas well. It can be described with reference to the above embodiments and will not be elaborated here.

[0209] Further, after the step of calculating the dynamic permeability of the reservoir gas well, the method for calculating the dynamic permeability of the reservoir gas well further includes:

[0210] Monitoring the dynamic permeability of the reservoir gas well, and predicting the remaining reserves of the gas reservoir according to the change trend of the dynamic permeability of the reservoir gas well. It can be described with reference to the above embodiments and will not be elaborated here.

[0211] Further, before the steps of obtaining the total formation coefficient according to well test data; obtaining the fluid production, wellbore flowing pressure and average formation pressure according to production logging; and obtaining the reservoir thickness according to logging data, the method for calculating the dynamic permeability of the reservoir gas well further includes:

[0212] The well test data and the logging data are obtained by geophysical methods. For details, reference may be made to the above embodiments and will not be elaborated herein.

[0213] Figure 2 It is a schematic structural diagram of a reservoir gas well dynamic permeability calculation device provided by an embodiment of the present invention. As Figure 2 shown, the reservoir gas well dynamic permeability calculation device provided by the embodiment of the present invention includes an acquisition unit 201 and a calculation unit 202, wherein:

[0214] The acquisition unit 201 is configured to obtain the total formation coefficient according to the well test data; obtain the fluid production, the wellbore flow pressure, and the average formation pressure according to the production logging; obtain the reservoir thickness according to the logging data; the calculation unit 202 is configured to calculate the reservoir gas well dynamic permeability according to the total formation coefficient, the fluid production, the wellbore flow pressure, the average formation pressure, and the reservoir thickness, and by using a pre-established reservoir gas well dynamic permeability model; wherein, the expression of the reservoir gas well dynamic permeability model is as follows:

[0215]

[0216] wherein, K i is the dynamic permeability of the reservoir gas well in the i-th layer, K'h is the total formation coefficient, q i is the fluid production, P wfi is the wellbore flow pressure, is the average formation pressure, h i is the reservoir thickness, and n is the total number of layers included in the reservoir gas well.

[0217] Specifically, the acquisition unit 201 in the device is configured to obtain the total formation coefficient according to the well test data; obtain the fluid production, the wellbore flow pressure, and the average formation pressure according to the production logging; obtain the reservoir thickness according to the logging data; the calculation unit 202 is configured to calculate the reservoir gas well dynamic permeability according to the total formation coefficient, the fluid production, the wellbore flow pressure, the average formation pressure, and the reservoir thickness, and by using a pre-established reservoir gas well dynamic permeability model; wherein, the expression of the reservoir gas well dynamic permeability model is as follows:

[0218]

[0219] wherein, K i is the dynamic permeability of the reservoir gas well in the i-th layer, K'h is the total formation coefficient, q i is the fluid production, P wfi is the wellbore flow pressure, is the average formation pressure, hi where \(h\) is the reservoir thickness and \(n\) is the total number of layers in the reservoir gas well.

[0220] The reservoir gas well dynamic permeability calculation device provided by the embodiments of the present invention obtains the total formation coefficient according to well test data; obtains the fluid production, wellbore flowing pressure, and average formation pressure according to production logging; obtains the reservoir thickness according to logging data; and calculates the dynamic permeability of the reservoir gas well according to the total formation coefficient, the fluid production, the wellbore flowing pressure, the average formation pressure, and the reservoir thickness, and by using a pre-established reservoir gas well dynamic permeability model, which can improve the accuracy of calculating the dynamic permeability of the reservoir gas well and has strong applicability.

[0221] The embodiments of the reservoir gas well dynamic permeability calculation device provided by the embodiments of the present invention can specifically be used to execute the processing procedures of the above-mentioned method embodiments, and its functions will not be elaborated here. Reference can be made to the detailed descriptions of the above-mentioned method embodiments.

[0222] Figure 3 is a schematic physical structure diagram of a computer device provided by an embodiment of the present invention. As Figure 3 shown, the computer device includes: a memory 301, a processor 302, and a computer program stored on the memory 301 and executable on the processor 302. When the processor 302 executes the computer program, the following method is implemented:

[0223] Obtain the total formation coefficient according to well test data; obtain the fluid production, wellbore flowing pressure, and average formation pressure according to production logging; obtain the reservoir thickness according to logging data;

[0224] Calculate the dynamic permeability of the reservoir gas well according to the total formation coefficient, the fluid production, the wellbore flowing pressure, the average formation pressure, and the reservoir thickness, and by using a pre-established reservoir gas well dynamic permeability model;

[0225] where the expression of the reservoir gas well dynamic permeability model is as follows:

[0226]

[0227] where \(K\) i is the dynamic permeability of the \(i\)-th layer of the reservoir gas well, \(K'h\) is the total formation coefficient, \(q\) i is the fluid production, \(P\) wfi is the wellbore flowing pressure, is the average formation pressure, \(h\) i is the reservoir thickness, and \(n\) is the total number of layers in the reservoir gas well.

[0228] This embodiment discloses a computer program product, which includes a computer program. When the computer program is executed by a processor, the following method is implemented:

[0229] Obtain the total formation coefficient according to well test data; obtain the fluid production rate, wellbore flowing pressure and average formation pressure according to production logging; obtain the reservoir thickness according to logging data;

[0230] According to the total formation coefficient, the fluid production rate, the wellbore flowing pressure, the average formation pressure and the reservoir thickness, and by using a pre-established dynamic permeability model of the reservoir gas well, calculate the dynamic permeability of the reservoir gas well;

[0231] Among them, the expression of the dynamic permeability model of the reservoir gas well is as follows:

[0232]

[0233] Among them, K i is the dynamic permeability of the reservoir gas well in the i-th layer, K'h is the total formation coefficient, q i is the fluid production rate, P wfi is the wellbore flowing pressure, is the average formation pressure, h i is the reservoir thickness, and n is the total number of layers included in the reservoir gas well.

[0234] This embodiment provides a computer-readable storage medium, which stores a computer program. When the computer program is executed by a processor, the following method is implemented:

[0235] Obtain the total formation coefficient according to well test data; obtain the fluid production rate, wellbore flowing pressure and average formation pressure according to production logging; obtain the reservoir thickness according to logging data;

[0236] According to the total formation coefficient, the fluid production rate, the wellbore flowing pressure, the average formation pressure and the reservoir thickness, and by using a pre-established dynamic permeability model of the reservoir gas well, calculate the dynamic permeability of the reservoir gas well;

[0237] Among them, the expression of the dynamic permeability model of the reservoir gas well is as follows:

[0238]

[0239] Among them, K i is the dynamic permeability of the reservoir gas well in the i-th layer, K'h is the total formation coefficient, q i is the fluid production rate, P wfi is the wellbore flowing pressure, is the average formation pressure, hi where \(h\) is the reservoir thickness and \(n\) is the total number of layers in the reservoir gas well.

[0240] Compared with the technical solutions in the prior art, the method for calculating the dynamic permeability of a reservoir gas well provided by the embodiments of the present invention obtains the total formation coefficient according to well test data; obtains the fluid production, wellbore flow pressure, and average formation pressure according to production logging; obtains the reservoir thickness according to logging data; and calculates the dynamic permeability of the reservoir gas well according to the total formation coefficient, the fluid production, the wellbore flow pressure, the average formation pressure, and the reservoir thickness, and by using a pre-established dynamic permeability model of the reservoir gas well, which can improve the calculation accuracy of the dynamic permeability of the reservoir gas well and has strong applicability.

[0241] Those skilled in the art should understand that the embodiments of the present invention can be provided as a method, a system, or a computer program product. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Moreover, the present invention can take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0242] The present invention is described with reference to the flowcharts and / or block diagrams of methods, apparatuses (systems), and computer program products according to embodiments of the present invention. It should be understood that each flow and / or block in the flowcharts and / or block diagrams, and the combination of flows and / or blocks in the flowcharts and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to the processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing devices to generate a machine, such that the instructions executed by the processor of the computer or other programmable data processing devices produce means for implementing the functions specified in Figure 1 one or more of the flows Figure 1 or blocks or combinations of blocks.

[0243] These computer program instructions can also be stored in a computer-readable memory that can direct a computer or other programmable data processing device to work in a specific manner, such that the instructions stored in the computer-readable memory produce a manufactured article including instruction means that implement the functions specified in Figure 1 one or more of the flows Figure 1 or blocks or combinations of blocks.

[0244] These computer program instructions can also be loaded onto a computer or other programmable data processing apparatus, so that a series of operation steps are executed on the computer or other programmable apparatus to produce a computer-implemented process, thereby the instructions executed on the computer or other programmable apparatus provide steps for implementing the functions specified in one process Figure 1 one process or multiple processes and / or blocks Figure 1 steps of the functions specified in one block or multiple blocks.

[0245] In the description of this specification, the descriptions with reference to the terms "one embodiment", "a specific embodiment", "some embodiments", "for example", "example", "specific example", or "some examples", etc. mean that the specific features, structures, materials, or characteristics described in connection with the embodiment or example are included in at least one embodiment or example of the present invention. In this specification, the schematic representations of the above terms do not necessarily refer to the same embodiment or example. Moreover, the specific features, structures, materials, or characteristics described can be combined in any one or more embodiments or examples in a suitable manner.

[0246] The specific embodiments described above have further elaborated the objectives, technical solutions, and beneficial effects of the present invention. It should be understood that the above are only specific embodiments of the present invention and are not used to limit the protection scope of the present invention. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principles of the present invention shall be included in the protection scope of the present invention.

Claims

1. A method for calculating the dynamic permeability of a reservoir gas well, characterized in that: include: Obtain the total formation coefficient based on well test data; Obtain fluid production, wellbore flowing pressure and average formation pressure based on production logging; Obtain reservoir thickness based on well logging data; According to the total formation coefficient, the fluid production, the wellbore flowing pressure, the average pressure of the formation and the reservoir thickness, and using a pre-established reservoir gas well dynamic permeability model, the reservoir gas well dynamic permeability is calculated; The expression of the reservoir gas well dynamic permeability model is as follows: Among them, K i is the dynamic permeability of the gas well in the i-th reservoir, K ′ h is the total formation coefficient, q i is the fluid production, P wfi is the wellbore flowing pressure, is the average pressure of the formation, h i is the reservoir thickness, and n is the total number of layers contained in the reservoir gas wells.

2. The reservoir gas well dynamic permeability calculation method according to claim 1, characterized in that: The reservoir gas well dynamic permeability calculation method also includes: The dynamic permeability of the reservoir gas well is calculated according to the following expression: K i =a i K Among them, a i is the contribution weight of the permeability of the i-th layer to the total permeability, and K is the theoretical value of the dynamic permeability of the total reservoir gas well.

3. The method for calculating the dynamic permeability of a reservoir gas well according to claim 2, characterized in that: According to the following expression, we can calculate a i :

4. The method for calculating the dynamic permeability of a reservoir gas well according to claim 1 or 2, characterized in that: After the step of calculating the dynamic permeability of the reservoir gas well, the method for calculating the dynamic permeability of the reservoir gas well further comprises: The dynamic permeability of the gas wells in the reservoir is monitored, and the production dynamics of the gas reservoir is predicted according to the changing trend of the dynamic permeability of the gas wells in the reservoir.

5. The reservoir gas well dynamic permeability calculation method according to claim 1 or 2, characterized in that: After the step of calculating the dynamic permeability of the reservoir gas well, the method for calculating the dynamic permeability of the reservoir gas well further comprises: The dynamic permeability of the gas wells in the reservoir is monitored, and the remaining reserves of the gas reservoir are predicted according to the changing trend of the dynamic permeability of the gas wells in the reservoir.

6. The method for calculating dynamic permeability of a reservoir gas well according to claim 1, characterized in that: Before the steps of obtaining the total formation coefficient according to the well test data; obtaining the fluid production, wellbore flow pressure and average formation pressure according to the production logging; and obtaining the reservoir thickness according to the logging data, the reservoir gas well dynamic permeability calculation method further includes: The well testing data and the well logging data are obtained by using geophysical methods.

7. A reservoir gas well dynamic permeability calculation device, characterized in that: include: An acquisition unit, used for acquiring total formation coefficients according to well test data; Obtain fluid production, wellbore flowing pressure and average formation pressure based on production logging; Obtain reservoir thickness based on well logging data; A calculation unit, for calculating the dynamic permeability of the reservoir gas well according to the total formation coefficient, the fluid production, the wellbore flowing pressure, the average pressure of the formation and the reservoir thickness, and using a pre-established reservoir gas well dynamic permeability model; The expression of the reservoir gas well dynamic permeability model is as follows: Among them, K i is the dynamic permeability of the gas well in the i-th reservoir, K ′ h is the total formation coefficient, q i is the fluid production, P wfi is the wellbore flowing pressure, is the average pressure of the formation, h i is the reservoir thickness, and n is the total number of layers contained in the reservoir gas wells.

8. A computer device comprising a memory, a processor and a computer program stored in the memory and executable on the processor, characterized in that: When the processor executes the computer program, the method according to any one of claims 1 to 6 is implemented.

9. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, the method according to any one of claims 1 to 6 is implemented.

10. A computer program product, characterized in that The computer program product comprises a computer program, and when the computer program is executed by a processor, the method according to any one of claims 1 to 6 is implemented.

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