Experimental method and device for measuring interlayer fluid channeling amount of water invasion rhythm gas reservoir of high-temperature and high-pressure large flat plate model

Abstract

The invention discloses an experimental method and device for measuring interlaminar fluid channeling of a large slab model water invasion rhythm gas reservoir under high-temperature and high-pressure conditions, and relates to the technical field of gas reservoir development. The pressure, the water saturation and compression factors of different temperature and pressure are measured through the experimental device, and the change of the water saturation of a single layer in the water invasion process is directly metered through the acoustoelectric data acquisition system, so that the theoretical output of each small layer can be accurately obtained, and interlayer interference and interlayer fluid channeling phenomena generated during three-layer and multi-layer commingling production can be analyzed; therefore, the contribution degree of the single-layer yield can be measured; real original stratum conditions can be simulated to carry out fixed-yield production, real production conditions are matched, stable flow is controlled, the situation that the experiment and the production process are different due to constant pressure control is avoided, and the change of water saturation in the displacement process can be directly obtained through an acoustoelectric data acquisition system; and the phenomenon of heterogeneous water invasion rhythm interlayer fluid channeling of the gas reservoir at high temperature and high pressure can be more intuitively reflected.

Description

Technical Field

[0001] This invention relates to the field of gas reservoir development technology, and in particular to a method for measuring interlayer flow rates in rhythmic water-intrusive gas reservoirs. Background Technology

[0002] Currently, a relatively mature series of technologies has been developed for the development of low-permeability gas reservoirs, but no specific technologies have been developed for the development of thick, low-permeability edge-water-drive gas reservoirs at sea. Offshore gas field development costs are very high, requiring high production from rare wells. Due to the low permeability, wells must be fractured to achieve economical production capacity. Planar heterogeneity, vertical inter-layer and intra-layer heterogeneity have a significant impact on development. Furthermore, due to the influence of inter-layer, intra-layer, and planar heterogeneity of reservoirs, water-drive gas reservoirs face three major development challenges: (1) severe inter-layer interference; (2) complex gas-water seepage mechanisms within vertical layers; and (3) low production from single wells in low-permeability planar heterogeneity. Therefore, to effectively solve these three contradictions, it is necessary to understand the seepage mechanism of thick heterogeneous gas reservoirs, explore the intra-layer flow patterns, and select reasonable exploitation measures.

[0003] The invention patent "Experimental Device and Method for Measuring Inter-layer Crossflow in Multi-layer Co-production Gas Wells" (Publication No. CN105089653A) provides a device that can accurately simulate actual working conditions in the laboratory to precisely measure the inter-layer crossflow in gas wells. However, this method uses columnar core samples for experiments and lacks the ability to detect saturation changes. Furthermore, this method is based on constant pressure steady-state production and fails to simulate exhaustion and water intrusion processes in a constant-production mode. The invention patent "Method and Device for Predicting Co-production Capacity of Multi-Reservoir Gas Reservoirs" (Publication No. CN112065339A) provides a method and device for predicting the co-production capacity of multi-reservoir gas reservoirs. However, this method fails to simulate real formation conditions, especially for oil and gas under high temperature and high pressure conditions. Under different temperature and pressure conditions, the gas properties will change, leading to deviations between experimental and theoretical data. The invention patent "A device and method for testing the saturation of three phases of oil, gas and water in a high-temperature and high-pressure flat plate model" (publication number CN112816394B) provides a device and method for testing the saturation of three phases of oil, gas and water under high temperature and high pressure. However, this method can only measure the resistivity and then indirectly calculate the water saturation and gas saturation through formulas. The calculation process is complex and the accuracy is reduced, which will lead to deviations in experimental data. The patent with application number CN202021297692.8 provides an experimental device for simulating multi-layer co-production of coalbed methane reservoirs. However, the device does not have a flow channel for gas exchange between the core holders, making it difficult to reflect the actual situation of interlayer crossflow. Currently, numerical simulation is often used to analyze the interlayer crossflow behavior in the process of multi-layer co-production of gas wells. However, this method is highly dependent on the accuracy of model establishment, the reliability of calculation results is limited by the accuracy of the physical mechanism description, and it is difficult to obtain effective experimental verification.

[0004] In summary, there is an urgent need to develop an experimental device and method that can realistically simulate the physical process of multi-layer synergistic gas reservoir production and accurately measure and quantify the interlayer flow rate between different sub-layers, in order to support the research and optimization of efficient development technologies for complex gas reservoirs. Therefore, this invention proposes an experimental device and method capable of measuring the interlayer flow rate in a high-temperature, high-pressure, large-plate model water-intrusion rhythmic gas reservoir. Addressing the interlayer interference phenomena generated during multi-layer synergistic production, it can simulate water intrusion under real original formation conditions using different water volume ratios, and conduct depletion extraction in a fixed-production mode, achieving stable flow rate production. Unlike the unstable flow rate under constant-pressure control, this method matches the experimental process with the real production process. Furthermore, the acoustic-electric data acquisition system can directly measure the change in water saturation of a single layer during water intrusion, thereby measuring the contribution of a single layer to production. This not only minimizes the impact of temperature and pressure changes on oil and gas properties but also allows for a more precise investigation of the influence of heterogeneous water intrusion, interlayer interference, and interlayer flow rate phenomena on the extraction process. Summary of the Invention

[0005] The purpose of this invention is to provide an experimental method for measuring interlayer flow in a large flat plate model of water-inundated rhythmic gas reservoir under high temperature and high pressure conditions. By calculating the flow rate and gas contribution rate of each layer, the interlayer interference and flow phenomenon of heterogeneous gas reservoirs are explored. This provides guidance for the exploitation method of fixed-yield production under the influence of intralayer heterogeneous water inundation rhythm. The principle is reliable, the operation is convenient, the experimental results are intuitive, and it has broad application prospects.

[0006] To achieve the above technical objectives, the present invention adopts the following technical solution:

[0007] Step S1: Determine the pressure and gas saturation of the rock slab using an experimental setup, and calculate the gas production of each sub-layer of the rock slab at each moment using a gas mass flow meter;

[0008] Step S2: Tightly attach the rubber sleeve containing 480 electrode plates to the rock slab, then connect the acoustic-electric data acquisition system to the rock slab and the computer. Based on the acoustic-electric data acquisition system, the water saturation at 480 points in the gas reservoir can be obtained. At this point, the gas saturation is:

[0009]

[0010] Step S3: Calculate the gas volume factor:

[0011]

[0012] In the formula: B gi -Gas volume coefficient under different pressures; Z i -Gas compressibility factor under different pressures; P i- Different pressures; t - Experimental temperature, °C; Psc - Standard atmospheric pressure, MPa;

[0013] Step S4: Convert the underground gas into the surface gas:

[0014]

[0015] In the formula: V sci -Ground gas volume under different pressures, ml; HCPV i - Hydrocarbon pore volume under different pressures;

[0016] Step S5: Sum and average the hydrocarbon pore volume (HCPV) at each point in the single layer to obtain the average hydrocarbon pore volume (HCPV) of that layer, and then combine it with the formula... Calculate the reserves V of each single layer under the target formation pressure. sc1 and remaining reserves V under target abandonment pressure sc2 Subtracting the two yields the theoretical output of that layer:

[0017]

[0018] Where: N i - The volume of gas leaving the monolayer at the ground, in ml; V sc1 - The volume of gas at the surface under the target's original formation pressure, in ml; V sc2 - The volume of residual gas at ground level under the target exhaust pressure, in ml;

[0019] Step S6: Subtract the theoretical production from the actual production for each layer to obtain the gas ingress or egress rate λ for each layer. The specific formula is as follows:

[0020]

[0021] In the formula, λ represents the cross-flow rate, ml. If λ > 0, it indicates the outflow rate of the layer; if λ < 0, it indicates the inflow rate of the layer. M i Actual yield of each layer as measured by experiments.

[0022] Furthermore, in step S1, the static parameters of the gas reservoir include pressure, temperature, porosity, permeability, and hydrocarbon pore volume (HCPV).

[0023] Furthermore, in step S1, the formula for calculating the actual output measured in each layer of the experiment is as follows:

[0024]

[0025] Among them, M i - Actual output measured in each layer of the experiment, in ml; Q i- Flow rate of each layer measured by mass flow meter, ml / min; t - time, min.

[0026] Further, in step S3, the calculation steps for the gas compressibility factor are as follows:

[0027] Step S3.1: Determine the experimental temperature and initial formation pressure. Pressure changes during the experiment can be measured by a pressure sensor.

[0028] Step S3.2: Calculate the gas compressibility factor under different pressure and temperature conditions. The equation is as follows:

[0029]

[0030] The convergence value of Z obtained using an iterative formula is the gas compressibility factor, and the formula is as follows:

[0031]

[0032] Where: Z - gas compressibility factor; Pr - gas relative pressure, MPa; T r -Gas relative temperature , ℃; ω - gas eccentricity factor.

[0033] Further, in step S4, the calculation step for the average hydrocarbon pore volume (HCPV) of the rock slab is as follows:

[0034] Step S4.1: The acoustic-electric scanning system has 480 points (12 rows × 40 columns), evenly distributed across the entire rock slab. The number of points evenly distributed across each layer and the size of each point can be calculated based on the slab's dimensions and the length or width of each layer. Then, the hydrocarbon pore volume (HCPV) at each point can be calculated using the following formula:

[0035]

[0036] in, —The volume of hydrocarbons in the pores at the first electrode point; —These are the length, width, and height of the first electrode point, respectively; — represents the water saturation at the first electrode point; —This represents the porosity of the first layer.

[0037] Therefore, we can conclude that:

[0038]

[0039]

[0040] Step S4.2: The number of electrodes corresponding to each sublayer needs to be evenly distributed based on the width of each sublayer and the width of the entire rock slab; the length, width, and height of each electrode point are equal, and each electrode point must correspond to the porosity of its layer. Therefore, the average hydrocarbon pore volume (HCPV) of the entire rock slab is:

[0041]

[0042] To achieve the above objectives, the present invention also provides an experimental apparatus for measuring the interlayer flow rate of a water-invaded rhythmic gas reservoir under high temperature and high pressure conditions in a large flat plate model. This experimental apparatus is used to experimentally measure the interlayer flow rate of a water-invaded rhythmic gas reservoir under high temperature and high pressure conditions in a large flat plate model. The apparatus is characterized by comprising: a fully automatic high-pressure displacement pump, a formation water intermediate container, a water pump, a sapphire gas-water separation device, a mass flow meter, an acoustic-electric data acquisition system, and a pressure sensor; the flat plate model contains a rock slab model, an acoustic-electric scanning device, and pressure measuring points, and has an injection end and a production end on both sides. The saturation pipeline port on the left side of the flat plate model connects to an intermediate container filled with formation water and a water pump simulating edge water. Different water volume ratios are achieved by manipulating the water pump to set the operating pressure difference and water replenishment rate. The water intrusion pipeline end is connected to a displacement pump, a formation water pressure vessel, and an intermediate gas container. The production end on the right side of the flat plate model connects to the inlet of a sapphire gas-water separator. This device mainly consists of a high-pressure gas-water separator and a high-pressure dryer, aiming to separate the produced gas and water while drying the moisture in the produced gas to ensure accurate measurement by the mass flow meter. The outlet of the sapphire gas-water separator is then connected to the mass flow meter. The gas extraction rate in the experiment is controlled by a high-pressure gas mass flow meter, and different gas extraction rates can be set directly through the operating interface to achieve fixed-production with different feed rates. An acoustic-electric data acquisition system is installed on the rock slab surface to detect the water intrusion sweep status and changes in the water saturation of the rock slab in real time.

[0043] Furthermore, the flat plate model includes a water intrusion pipeline, a saturation pipeline, pressure measuring points, and a production well; the water intrusion pipeline and the saturation pipeline on the left are connected to the corresponding equipment through high-temperature and high-pressure pipelines and valves, respectively; the production end on the right is connected to a sapphire gas-water separation device; the model is also connected to an acoustic and electrical data acquisition system, pressure and temperature sensors, a confining pressure pump, and a vacuum pump.

[0044] Furthermore, the sapphire gas-water separation device mainly consists of a high-pressure gas-water separator and a high-pressure dryer; the produced well is connected to the corresponding high-pressure gas-water separator and high-pressure dryer in sequence through high-temperature and high-pressure pipelines and valves.

[0045] Furthermore, the high-pressure gas mass flow meter is connected to the outlet end of the corresponding high-pressure drying pipe, and each mass flow meter is connected to the corresponding data acquisition system, which can monitor the changes in the gas production rate of the single layer in real time.

[0046] Furthermore, the water simulation device includes a water pump, a water parameter system, a water pressure vessel, and a pressure sensor. The water parameter system is connected to the top of the water pump, and the formation water pressure vessel is connected to the right side. The formation water pressure vessel is then connected to the saturation pipeline of the flat plate model, and a pressure sensor is installed on this pipeline. Pressure measurement points are set inside the rock slab model, and pressure sensors are connected to the outside of the model, allowing real-time observation of pressure changes inside the rock slab during the experiment.

[0047] The present invention has the following beneficial technical effects:

[0048] This invention can not only simulate real original formation conditions for fixed-yield production, match real production conditions, control stable flow, and avoid differences between the experimental and production processes caused by constant pressure control, but also directly obtain the changes in water saturation during the displacement process through an acoustic and electrical data acquisition system. It can also intuitively reflect the phenomenon of interlayer flow of heterogeneous water intrusion rhythm under high temperature and high pressure. By measuring the pressure, water saturation, and compressibility factors at different temperatures and pressures, it can accurately obtain the theoretical output of each sub-layer, and analyze the interlayer interference and interlayer flow phenomenon generated during the combined production of three or more layers. It has a wide range of applications and is highly practical. Attached Figure Description

[0049] Figure 1 This is a schematic diagram of the device structure provided in the embodiments of the present invention;

[0050] Numbers in the diagram: 1-Fully automatic displacement pump; 2-Water pump; 3-Water parameter system; 4-Formation water pressure vessel; 5-Formation water intermediate container; 6-Gas intermediate container; 7, 10-Pressure sensor; 8-Acoustic and electrical data collection system; 9-Temperature control switch; 11-Containing pressure pump; 12-Vacuum pump; 13, 14, 15-High-pressure gas-water separator; 16-Sapphire gas-water separator; 17, 18, 19-High-pressure gas drying tube; 20, 21, 22-Gas mass flow meter; 23, 24, 25-Gas flow detection system; 26-High-temperature and high-pressure flat plate model system; 27, 28, 29, 30, 31, 32, 33, 34, 35, 36, 37, 38, 39, 40, 41, 42, 43, 44, 45-Valve.

[0051] Figure 2 This is a schematic diagram of a cross-section of a rock slab provided in an embodiment of the present invention;

[0052] The diagram is labeled as follows: 46 - Saturation pipeline; 48 - First layer production well; 49 - Second layer production well; 50 - Third layer production well; 51 - Sand-filled model; 52 - Flat plate model; 55 - Water-inundated pipeline; 47 - First layer rock slab model; 56 - Second layer rock slab model; 53 - Third layer rock slab model; 54 - Vessel model; 57, 58, 59, 60, 61, 62, 63, 64, 65 - Pressure measurement points.

[0053] Figure 3 This is a flowchart illustrating the implementation of the device and method for measuring the interlayer crossflow of water invading rhythm in heterogeneous gas reservoirs provided in this embodiment of the invention.

[0054] Figure 4 This is a graph showing the variation of gas crossflow in a single layer in a specific embodiment;

[0055] Figure 5 This is a graph showing the variation of water production in a single layer in a specific embodiment; Figure 6 This is a graph showing the variation of single-layer gas recovery rate in a specific embodiment. Detailed Implementation

[0056] To enable those skilled in the art to better understand the technical solutions in this specification, the technical solutions in the embodiments of this specification will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this specification, and not all embodiments. Based on the embodiments in this specification, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of this specification.

[0057] In actual oil and gas field development, natural gas reservoirs typically develop into multiple sub-layers vertically. These sub-layers exhibit significant differences in reservoir properties such as porosity and permeability, leading to substantial variations in their flow capacity. Because developing a single sub-layer is costly and inefficient, industrial practice often employs multi-layer co-production, simultaneously exploiting multiple reservoir sub-layers through a single well. However, the separators separating these sub-layers often possess some permeability and cannot completely prevent gas movement across layers, inevitably resulting in inter-layer flow during development. Therefore, in-depth research into the specific location and flow rate of inter-layer flow is crucial for accurately assessing its impact on the overall reservoir development.

[0058] The present invention will be further described below with reference to specific embodiments and accompanying drawings.

[0059] An experimental apparatus for measuring interlayer flow in a water-invaded rhythmic gas reservoir under high temperature and high pressure conditions using a large flat plate model is characterized by comprising a fully automatic high-pressure displacement pump 1, a formation water intermediate container 5, a water pump 2, a sapphire gas-water separation device 16, mass flow meters 20-22, an acoustic-electric data acquisition system 8, and pressure sensors 7 and 10; the flat plate model 52 contains rock slab models 47, 53, and 56, an acoustic-electric scanning device 8, and pressure measuring points 57-65, and has injection ends 46 and 55 and production ends 48-50 on both sides. The saturation pipeline 46 on the left side of the flat plate model 52 is connected to an intermediate container 4 filled with formation water and a water pump 2 to simulate edge water. Different water volume ratios are achieved by manipulating the pressure difference and water replenishment rate of water pumps 2 and 3. The water intrusion pipeline 55 is connected to a displacement pump 1, a formation water pressure vessel 5, and a gas intermediate container 6. The extraction end on the right side of the flat plate model 52 is connected to the inlet of a sapphire gas-water separator 16. This device mainly consists of a high-pressure gas-water separator 13-15 and a high-pressure dryer 17-19. Its purpose is to separate the produced gas and water while drying the moisture in the produced gas to ensure accurate measurement by the mass flow meter 20-22. Then, the outlet of the sapphire gas-water separator 16 is connected to the mass flow meter 20-22. The gas extraction rate in the experiment is controlled by the high-pressure gas mass flow meter 20-22. Different gas extraction rates can be set directly through the operating interface to achieve fixed-production with different formulations. By mounting the acoustic and electrical data acquisition system onto the surface of the rock slab, the water intrusion status and changes in the water saturation of the rock slab can be detected in real time.

[0060] Furthermore, the flat plate model 52 includes a water intrusion pipeline 55, a saturation pipeline 46, pressure measuring points 57-65, and a production well; the water intrusion pipeline 55 and the saturation pipeline 46 on the left are connected to the corresponding equipment through high-temperature and high-pressure pipelines and valves, respectively; the production end 48-50 on the right is connected to the sapphire gas-water separation device 16; the model is also connected to an acoustic and electrical data acquisition system 8, pressure and temperature sensors 9 and 10, a confining pressure pump 11, and a vacuum pump 12.

[0061] Furthermore, the sapphire gas-water separation device 16 mainly consists of a high-pressure gas-water separator 13-15 and a high-pressure dryer 17-19; the produced well is connected to the corresponding high-pressure gas-water separator 13-15 and high-pressure dryer 17-19 in sequence through high-temperature and high-pressure pipelines and valves.

[0062] Furthermore, the high-pressure gas mass flow meter 20-22 is connected to the outlet end of the corresponding high-pressure drying tube 17-19, and each mass flow meter 20-22 is connected to the corresponding data acquisition system 23-25, which can monitor the change in gas production rate of a single layer in real time.

[0063] Furthermore, the water simulation device includes a water pump 2, a water parameter system 3, a water pressure vessel 4, and a pressure sensor 7. The water pump 2 is connected to the water parameter system 3 at the top and to the formation water pressure vessel 4 on the right side. The formation water pressure vessel 4 is then connected to the saturation pipeline 46 of the flat plate model, on which the pressure sensor 7 is installed. The rock slab model has multiple pressure measurement points 57-65 evenly distributed in each small layer inside. The pressure sensor 10 is connected to the outside of the model, which can observe the changes in internal pressure of the rock slab in real time during the experiment.

[0064] The specific experimental steps are as follows:

[0065] (1) Mix quartz sand and binder with different sand-to-binder ratios, compact the mortar mixture with equal force, and after drying, drill core samples to test the permeability. The stability and reliability of the formula are verified by repeated experiments.

[0066] (2) Based on the selected permeability formulas for the core samples of the n strata, calculate the required mass of quartz sand and binder A / B for each stratum, and mix them evenly according to the ratio. Pour the sand-binder mixture into the rock slab model and compact it under the same conditions to ensure that the permeability of the rock slab model meets the target.

[0067] (3) Use a vacuum pump to evacuate the model to check its airtightness. If it is good, fill the vessel; if it leaks, check the seal and refill if necessary until a qualified rock slab model is obtained.

[0068] (4) Flip the rock slab horizontally to the required angle for the experiment, place it into the reactor, and set the assembled model at the required angle to the horizontal.

[0069] (5) Connect the water pump, sapphire separator, flow meter and pipeline.

[0070] (6) Using a fully automatic displacement pump, inject the pre-prepared formation water into the flat plate model at a slow rate to gradually increase the internal pressure to the target pressure. Simultaneously establish confining pressure and back pressure. During the pressure building process, it is important to ensure that the back pressure is always 2-4 MPa greater than the internal pressure and the confining pressure is 5-7 MPa greater than the internal pressure to avoid operational errors that could cause rock plate leakage and lead to experimental failure. After the pressure stabilizes, let it stand for 10 minutes to confirm that the formation pressure gauge does not drop. Then, start the temperature control, gradually increase the temperature to the target value and maintain it at a constant temperature to complete the pressure building and heating process.

[0071] (7) Flip the model to the required angle for the experiment. While injecting hydraulic oil to establish confining pressure, first inject water from the bottom water intrusion pipeline of the rock slab. When water is seen at the production end, flatten the rock slab and continue to inject water from the top saturation pipeline to saturate the formation. The purpose is to make the formation water saturation more uniform. When the water injection rate of the saturation pipeline is equal to the water output rate of the production well, saturation ends, and V is measured. 水1 =V 注 -V 出An acoustic-electric data acquisition system was used to scan the formation water distribution in the rock slab, obtaining the saturation field and confirming the saturation effect. Experimental gas was then injected through the upper saturation pipeline until no more water was produced at the extraction end, and the volume of water displaced was measured as V. 水2 Therefore, the degree of saturation of bound water = 1 - V 水2 / V 水1 gas saturation .

[0072] (8) Measurement of formation water compressibility:

[0073] First measurement: Determining the formation water volume V w The volume of residual hydraulic oil in the displacement pump, V o Target pressure P and pressure difference ΔP. V w Add the hydraulic fluid to the intermediate container, then connect its injection end to the fully automatic displacement pump while simultaneously closing the extraction end valve. At this point, increase the pressure in the intermediate container to P, and read the remaining hydraulic fluid volume V in the pump. o1 Once the pump pressure and volume readings stabilize, reduce the pressure according to ΔP, while simultaneously metering the remaining hydraulic oil volume V in the pump. o2 Repeat the above steps until the pressure drops to atmospheric pressure, and record the remaining hydraulic oil volume V. o3 ...V on At this time, V on= V o The change in hydraulic oil volume is further calculated using the following formula:

[0074] ;

[0075] Second measurement: After removing the formation water, the volume of hydraulic oil in the pump should still be V. o Keep it unchanged. Close the outlet of the displacement pump and increase the pressure inside the pump to P; read the volume of hydraulic oil in the pump at this time, D1. Then, gradually decrease the target pressure to atmospheric pressure by ΔP, and record the volume of hydraulic oil in the pump after each pressure reduction, D2, D3...D... n ,at this time Similarly, the change in hydraulic oil volume can be calculated using the following formula:

[0076] ;

[0077] Because the first measurement included two-phase changes in hydraulic oil and formation water, while the second measurement only measured changes in hydraulic oil, and the V of the hydraulic oil... o Since it is equal to ΔP, the change in formation water when a single pressure difference is reduced is given by the following formula:

[0078]

[0079] The formation water compressibility coefficient and water replenishment rate are further calculated using the following formulas:

[0080]

[0081]

[0082] In the formula, - Water replenishment rate, μL / psi; C w - Formation water compressibility, MPa⁻¹; - Water volume ratio.

[0083] (9) Constant-yield water intrusion exhaustion experiment: n-layer model requires n mass flow meters. To ensure the mass flow meters are used without damage, install and turn on the gas-liquid separation and drying device to separate the produced gas and water while drying the water in the produced gas, so that the gas flowing through the mass flow meters is dry gas. Set one mass flow meter to the required flow rate to control the constant-yield production of the production well. Set the remaining n-1 high-pressure mass flow meters to the upper limit flow rate, do not control the output, only measure the output of each layer of n-1 layers, and set the flow meter gas flow rate according to the required production size of the experiment. Stop production when the outlet pressure of the flat plate model exhausts to the waste pressure;

[0084] A method for measuring interlayer flow in a water-fluvialized rhythmic gas reservoir under high temperature and high pressure conditions using a large flat plate model is disclosed. This method is based on an experimental apparatus for measuring interlayer flow in a water-fluvialized rhythmic gas reservoir under high temperature and high pressure conditions. The specific method for determining the interlayer flow includes the following steps:

[0085] (1) Determine the static parameters of the gas reservoir, including pressure, temperature, porosity, permeability, and HCPV;

[0086] (2) Fit the rubber sleeve containing 480 electrode plates tightly to the rock slab (to prevent leakage due to gaps under high pressure), then connect the acoustic and electrical data acquisition system to the rock slab and the computer and verify that the acoustic and electrical system can be used without error.

[0087] (3) Based on the acoustic and electrical data acquisition system, the water saturation and gas saturation at 480 points in the gas reservoir can be obtained. The average HCPV of each layer of the rock slab can be calculated. Based on the HCPV and gas compressibility factor, the actual gas output of each layer can be calculated. Then, the flow rate can be calculated by combining the output measured by the experiment of each small layer.

[0088] The above-mentioned method for measuring interlayer flow rate in a large flat plate model water-transgressive rhythmic gas reservoir under high temperature and high pressure conditions includes the following steps for calculating the average HCPV of the rock plate:

[0089] The acoustic-electric scanning system has 480 points (12 rows × 40 columns), evenly distributed across the entire rock slab. The number of points evenly distributed across each layer and the size of each point can be calculated based on the slab's dimensions and the length or width of each layer. Then, the HCPV of each point can be calculated using the following formula:

[0090]

[0091] in, —The volume of hydrocarbons in the pores at the first electrode point; —These are the length, width, and height of the first electrode point, respectively; — represents the water saturation at the first electrode point; —This represents the porosity of the first layer.

[0092] Therefore, we can conclude that:

[0093]

[0094]

[0095] It is worth noting that the number of electrodes corresponding to each sublayer needs to be evenly distributed based on the width of each sublayer and the overall width of the rock slab; the length, width, and height of each electrode point are equal, and each electrode point must correspond to the porosity of its respective layer. Therefore, the average HCPV of the entire rock slab is:

[0096]

[0097] The method described above for measuring interlayer flow in a water-prone rhythmic gas reservoir under high temperature and high pressure conditions using a large flat plate model includes the following steps for calculating the gas compressibility factor:

[0098] (1) Determine the experimental temperature and the original formation pressure. The pressure changes during the experiment can be measured by a pressure sensor.

[0099] (2) The Peng-Robinson equation of state is used to calculate the gas compressibility factor under different pressure and temperature conditions. The equation is as follows:

[0100]

[0101] The convergence value of Z obtained using an iterative formula is the gas compressibility factor. The formula is as follows:

[0102]

[0103] Where: Z - gas compressibility factor; Pr - gas relative pressure, MPa; T r -Gas relative temperature , ℃; ω - gas eccentricity factor;

[0104] The above-mentioned method for measuring interlayer flow rate in a water-prone rhythmic gas reservoir under high temperature and high pressure conditions, wherein the flow rate calculation steps are as follows:

[0105] (1) Record the water saturation of each sublayer under the target pressure, then the gas saturation is: ;

[0106] (2) After obtaining the gas compressibility factor from the above formula, the gas volume coefficient formula is further calculated based on the formula.

[0107]

[0108] In the formula: B gi -Gas volume coefficient under different pressures; Z i -Gas compressibility factor under different pressures; P i - Different pressures; t - Experimental temperature, °C; Psc - Standard atmospheric pressure, MPa;

[0109] (1) Based on the gas volume coefficient formula under different pressure states, the gas in the underground state can be converted into the gas in the surface state. The specific formula is as follows:

[0110]

[0111] In the formula: V sci -Ground gas volume under different pressures, ml; HCPV i - Hydrocarbon pore volume (volume of gas underground) under different pressures;

[0112] (2) Based on the experimentally measured water saturation under the target formation pressure and the water saturation under the target abandonment pressure, the gas saturation can be calculated. Given the thickness, length, porosity, temperature, and pressure of a certain layer, the number of acoustic and electrical data measurement points for that layer is first calculated. Then, the water saturation and gas saturation at each point can be experimentally measured. Next, based on the basic parameters and gas saturation, the gas compressibility factor and HCPV at each point under the target formation pressure and target waste pressure are calculated. The HCPV at each point in a single layer is then summed and averaged to obtain the average HCPV of that layer. Finally, this is combined with the formula... Calculate the reserves V of each single layer under the target formation pressure. sc1 and remaining reserves V under target abandonment pressure sc2 Subtracting the two yields the theoretical output of that layer, as shown in the formula:

[0113] (Excluding cross-platform traffic)

[0114] Where: N i- The volume of gas leaving the monolayer at the ground, in ml; V sc1 - The volume of gas at the surface under the target's original formation pressure, in ml; V sc2 - The volume of residual gas at ground level under the target exhaust pressure, in ml.

[0115] Similarly, the theoretical output of each of the other layers can be calculated using the steps described above. i The actual output of each layer (after flow rate) is measured experimentally. The specific formula is as follows:

[0116] ,

[0117] Among them, M i - Actual output measured in each layer of the experiment. ml; Q i - Flow rate of each layer measured by mass flow meter, ml / min; t - time, min.

[0118] Subtracting the actual output from the theoretical output of each layer yields the amount of gas entering (leaking) from each layer. The specific formula is as follows:

[0119] ;

[0120] In the formula, is For cross-flow, ml, if >0 indicates the amount of leakage from that layer; if <0 indicates the amount of intrusion into this layer.

[0121] In addition, the extraction degree of a single layer can be calculated. The specific formula is as follows:

[0122] ,

[0123] In the formula: - Single-layer recovery rate, %

[0124] Single-layer output contribution The specific formula is as follows:

[0125]

[0126] In the formula: -Contribution of output per layer, %

[0127] Example 1

[0128] This invention provides an experimental apparatus and method for measuring interlayer channeling flow in a high-temperature, high-pressure large flat plate model water-transgressive rhythmic gas reservoir. Figure 1 This is a schematic diagram of the device structure of the present invention. Figure 2This is a schematic cross-sectional view of the rock slab of the present invention. It includes a vessel model 54 with a maximum temperature and pressure of 150℃ and 70MPa. Inside, there is a flat plate model 52 and a sand-filled model 51. A saturation pipeline 46 is installed above the flat plate model, and a water intrusion pipeline 55 is installed on the left side. Nine pressure measurement points 57-65 are installed on the flat plate model, and a pressure sensor 10 is connected externally. A confining pressure pump 11 and a vacuum pump 12 are also connected externally to the flat plate model. The saturation pipeline 46 is connected to a water simulation system; the water intrusion pipeline 55 is connected to a displacement system; the right side of the flat plate model 5 is connected to a sapphire gas-water separator 16, which is then connected to a high-pressure gas mass flow meter.

[0129] The vessel model 54 is mainly composed of a flat plate model 52 and a sand-filled model 51. The vessel model can withstand a maximum temperature of 150℃ and a pressure of 70MPa, and is connected to a confining pressure pump 11 externally.

[0130] The flat plate model 52 has a length, width, and height of 100cm × 30cm × 1cm. It contains a saturation pipeline 46, production wells 48, 49, and 50, a sand-filling model 51, a water-invaded pipeline 55, and nine pressure measurement points 57-65. It is also connected to an external pressure sensor 10.

[0131] The right-side extraction end of the flat plate model 52 is sequentially connected to a sapphire gas-water separator 16 and a high-pressure gas mass flow meter 20-22, forming an output end control device.

[0132] Specifically, the sapphire gas-water separation device 16 is divided into two parts: high-pressure gas-water separators 13, 14, and 15, and high-pressure gas drying pipes 17, 18, and 19. The production wells 48, 49, and 50 of the three-layer model are connected to the high-pressure gas-water separators and the high-pressure gas drying pipes, respectively.

[0133] Specifically, the output gas velocity is controlled by high-pressure gas mass flow meters 20, 21, and 22; mass flow meters 20 and 21 are connected to high-pressure gas drying tubes 42 and 43; secondly, mass flow meter 22 is connected to mass flow meters 20 and 21 and high-pressure drying tube 44 to measure the total output gas. Furthermore, each mass flow meter is connected to a corresponding data collection system 23, 24, and 25, allowing for real-time monitoring of gas flow rate changes.

[0134] The sand-filled model 51 is made of 70-140 mesh quartz sand and UJ-100 binder mixed in various proportions to achieve the porosity and permeability required for the experiment. The sand-filled model consists of three layers: 47, 53, and 56, with a vacuum pump 12 connected to the right side of the model.

[0135] The water simulation system includes a water pump 2, a water parameter system 3, and a formation water pressure vessel 4, which are connected to a saturation pipeline port 46. A pressure sensor 7 is installed on the pipeline.

[0136] The displacement system includes a displacement pump 1, a formation water intermediate container 5, a gas intermediate container 6, and is connected to a water intrusion pipeline 55.

[0137] Example 2

[0138] This embodiment provides an experimental method for measuring the interlayer flow rate of a water-prone rhythmic gas reservoir using the experimental apparatus described in Embodiment 1. Figure 3 This is a flowchart illustrating the implementation method of the present invention. This apparatus and method can not only simulate the extraction of heterogeneous water-entrapped rhythmic gas reservoirs under real geological conditions with a fixed production rate, but also accurately detect the single-layer contribution of each sub-layer and further accurately calculate interlayer flow. The specific implementation method includes the following steps:

[0139] First, the process of making slabs:

[0140] (1) Select 70-140 mesh quartz sand and UJ-100 binder and mix them in various proportions. Then, press the mortar mixture into a paper cup with the same force. After drying, drill the core and measure the permeability of the core using an SCMS-C3 fully automatic core permeability tester. Repeat the above steps to design ten sand filling formula trials and sand filling model trials. Each group is repeated twice to reduce errors and verify the stability and reliability of the formula. Based on the experimental data, the target permeability formula required for the model was successfully produced: low permeability layer K1 (1 mD), medium permeability layer K2 (15 mD), and high permeability layer K3 (60 mD).

[0141] (2) Since the dimensions of the rock slab are 100cm×30cm×1cm, and the width of layer K1 is 8cm, layer K2 is 16.6cm, and layer K3 is 5.4cm, the sand should be filled in layers according to the dimensions of each layer. Based on the core permeability formula of the three layers previously selected, calculate the mass of quartz sand, type A cementitious agent, and type B cementitious agent required for each layer, and then mix the sand and cement according to the formula ratio and stir evenly. Then pour the sand and cement mixture into the flat plate model in layers and compact it. The compaction conditions should be consistent with those when the core formula was developed to ensure that the permeability of the rock slab model meets the requirements.

[0142] Second, model validation and assembly:

[0143] (1) At this time, turn on vacuum pump 12 and valve 34, and close valves 30, 31, 35, 36 and 37 to evacuate the rock slab 51 and test the airtightness of the rock slab model. If the airtightness is good, the next step of filling the rock slab model into the vessel can be carried out; if there is a problem with the airtightness, the sealing of the device needs to be checked, and if necessary, the rock slab should be refilled until a rock slab model that meets the requirements and has good airtightness is produced.

[0144] (2) After the airtightness check is correct, flip the rock slab horizontally and place it vertically into the vessel at 90° to the ground. Then set the assembled vessel model at a 5° angle to the horizontal.

[0145] Third, establish stratigraphic conditions:

[0146] Rotate the vessel model counterclockwise by 90° and open valves 26, 28, and 31. Figure 1 The fully automatic displacement pump 1 slowly passes the pre-prepared formation water through... Figure 2 Water is injected into the flat plate model through the water intrusion pipeline 54. When water begins to emerge from the production well 49, the vessel is leveled. At this point, valve 31 is closed, and valve 30 is opened to... Figure 2 The saturation pipe 45 at the top of the rock slab continues to be saturated with water to ensure uniform saturation. The internal pressure of the rock slab is gradually increased to 37 MPa. Simultaneously, valve 33 is opened, and hydraulic oil is injected into the annular space of the reactor body using the confining pressure pump 11 to establish confining pressure, simulating the pressure of the overlying rock. Then, valves 35-44 are fully opened, connecting the sapphire gas-water separator 14 and high-pressure gas mass flow meters 20, 21, and 22 (the high-pressure mass flow meters used in this invention have a pressure higher than 37 MPa, therefore no additional back pressure valve is needed). The purpose of the sapphire gas-water separator is to separate the produced gas and water, and to dry the produced gas to prevent damage to the gas mass flow meters. During the pressure build-up process, it is important to always maintain the back pressure greater than the internal pressure by 2-4 MPa and the confining pressure greater than the internal pressure by 5-7 MPa to avoid operational errors that could cause rock slab leakage and experimental failure. After the pressure stabilizes, wait 30 minutes and carefully observe the readings of the formation pressure gauge to ensure that the values ​​do not decrease. Then, the temperature control switch was activated to gradually raise the internal temperature of the vessel to 20°C, and then maintained a constant temperature after reaching the target temperature. At this point, the pressure build-up and heating process was successfully completed.

[0147] Fourth, establish bound water saturation.

[0148] When establishing stratigraphic conditions, wait until Figure 2 When the injection rate of the upper saturation pipeline 45 equals the water production rate of the K3 layer producing well 49, the formation water saturation ends, and V is measured. 水1 =V 注 -V 出 Then, valve 28 is closed, and valves 27, 30, and 32 are opened. Nitrogen gas is then injected through saturation pipeline 45 until no more water is produced from production well 49 in layer K3. The volume of water produced by displacement is measured to be V. 水2 Therefore, the bound water saturation S W =1-V 水2 / V 水1 gas saturation .

[0149] Fifth, measure the compressibility of formation water:

[0150] use Figure 1 The compressibility coefficient of formation water was measured between the intermediate displacement pump 1 and the intermediate formation water container 5. The specific steps are as follows:

[0151] First measurement: First, determine the formation water volume Vw and weigh it using a graduated cylinder, and also measure the remaining hydraulic oil volume V in the displacement pump. o The target pressure was set at 37 MPa and the differential pressure at 500 psi. The weighed formation water was then added to intermediate container 5, and its injection end was connected to the fully automatic displacement pump 1. Valve 26 was opened while the production end valve 28 was closed. At this point, the pressure in the intermediate container was increased to 37 MPa, and the remaining hydraulic oil volume V in the pump was recorded. o1 Once the pump pressure and volume readings stabilize, reduce the pressure to the calibrated differential pressure of 500 psi, while simultaneously reducing the remaining hydraulic oil volume V in the metering pump. o2 Repeat the above steps until the pressure drops to atmospheric pressure, and record the remaining hydraulic oil volume V. o3 ...V on At this point, the remaining hydraulic oil volume Von should be equal to the initially determined hydraulic oil volume V. o They are equal; further calculations are performed to determine the change in hydraulic oil volume, using the following formula:

[0152] ;

[0153] Second measurement: After the first measurement is completed, depressurize intermediate container 5 until the pressure inside the container is atmospheric pressure, then remove the intermediate container containing formation water. At this point, the volume of hydraulic oil in displacement pump 1 should remain constant at V. Next, close valve 26 and increase the pressure inside the pump to 37 MPa again; record the volume of hydraulic oil in the pump at this point, D1. Then, gradually reduce the target pressure to atmospheric pressure at a pressure difference of 500 psi, recording the volume of hydraulic oil in the pump after each pressure reduction: D2, D3…D… n ,at this time Similarly, the change in hydraulic oil volume can be calculated using the following formula:

[0154] ;

[0155] Since the first measurement included changes in both hydraulic oil and formation water, while the second measurement only measured changes in hydraulic oil, and the initial volume and pressure difference ΔP of the hydraulic oil were equal in both measurements, the specific formula for the change in formation water when the single pressure difference is reduced is as follows:

[0156]

[0157] The formation water compressibility coefficient and water replenishment rate are further calculated using the following formulas:

[0158] ,

[0159] in, - Water replenishment rate, μL / psi; C w - Formation water compressibility, MPa -1 ; - Water volume ratio.

[0160] The specific measurement results of the formation water compressibility coefficient are shown in Table 1:

[0161]

[0162] Sixth, constant yield water intrusion attenuation experiment

[0163] After establishing the bound water saturation, an acoustic-electric system scan was initiated, measuring the water saturation at 480 points. After obtaining the initial water saturation data for the rock slab, valves 26, 27, 28, 32, and 30 were closed, while the remaining valves were opened. The calculated water replenishment rate and experimental pressure difference were input into water pumps 2 and 3, which were connected to pre-mixed formation water, to simulate a 50-fold water intrusion. Then, the outlet of the intermediate container was connected to... Figure 2 The rock slab water intrusion pipeline 54 is connected, and the three unconnected extraction pipeline ports 47, 48, and 49 are sequentially connected to high-pressure gas-water separators 13, 14, and 15 to measure the water production. The results are shown below. Figure 5 The gas-liquid separator is connected to high-pressure drying pipes 17, 18, and 19 to dry the moisture in the produced gas. The flow rate is set to 500 ml / min using mass flow meter 22 to control the combined production of layers K1, K2, and K3 at a fixed output. The other two mass flow meters 20 and 21 are set to an upper limit flow rate of 1000 ml / min, and do not control the output; they only monitor the output of single layers K1 and K2.

[0164] Following well production, at 13 minutes into the experiment, water pump 2, confining pressure pump 11, and mass flow meter detection systems 23, 24, and 25 were paused; valves 29, 31, 33, 35, 36, and 37 were closed, and the acoustic-electric scanning system was activated to observe the water intrusion and saturation changes. Pressure sensor 10 was used to detect the pressure data within the rock slab at this time. After the scan was completed, water pump 2, confining pressure pump 11, and mass flow meter detection systems 23, 24, and 25 were restarted; valves 29, 31, 33, 35, 36, and 37 were reopened to resume production. The above scanning steps were repeated at 75 minutes into the experiment. Production was stopped when the outlet pressure of the flat plate model deteriorated to the abandoned pressure of 5 MPa; after water intrusion, a final acoustic-electric system scan was performed. The residual gas saturation at 480 points was measured, and the average HCPV of a single layer of rock slab after water intrusion was calculated using the formula. e This allows for the calculation of the remaining reserves of a single layer at an abandonment pressure of 5 MPa.

[0165] Seventh, further, calculate the initial reserves of a single layer, the remaining reserves of a single layer at the abandonment pressure, and the remaining reserves of a single layer after depletion to 13 minutes and 75 minutes, respectively. The specific calculation steps are as follows:

[0166] (1) Determine the experimental temperature and pressures P1, P2, P3, and P4 at different times.

[0167] (2) The Peng-Robinson equation of state was used to calculate the gas compressibility factor under conditions P1, P2, P3, P4, and 20℃. Then, the gas volume coefficient formula under different pressures was further calculated based on the formula, the specific formula being:

[0168]

[0169] In the formula: B gi -Gas volume coefficient under different pressures; Z i -Gas compressibility factor under different pressures; P i - Different pressures; t - Experimental temperature, °C; Psc - Standard atmospheric pressure, MPa;

[0170] (3) Based on the gas volume coefficient formula under different pressure states, and combined with the definition of the gas volume coefficient... The gas currently in its underground state can be converted into gas in its surface state using the following formula:

[0171]

[0172] In the formula: V sci -Ground gas volume under different pressures, ml; HCPV i - Hydrocarbon pore volume (gas volume underground) under different pressures; detailed calculation results are shown in Table 2:

[0173]

[0174] Eighth, calculate the crossflow.

[0175] Based on the water saturation measured at 37 MPa and 5 MPa in the above experiments, the gas saturation at the two pressures was calculated. Given the thickness, length, porosity, temperature, and pressure of a certain layer, the number of acoustic and electrical data measurement points for that layer is first calculated based on the ratio of the single-layer width to the rock slab width. Then, the water saturation and gas saturation at each point are experimentally measured. Next, the gas compressibility factor Z at 37 MPa and 5 MPa is calculated based on the basic parameters and gas saturation. iThe average HCPV of a single layer is obtained by summing and averaging the HCPVs of all points in the layer, and then combining this with the formula... Calculate the reserves V of a single layer at 37 MPa. sc1 and remaining reserves V at 5MPa sc2 Subtracting the two yields the theoretical output of that layer, as shown in the formula:

[0176]

[0177] Where: N i - The volume of gas leaving the monolayer at the ground, in ml; V sc1 - The volume of gas at the surface under the target's original formation pressure, in ml; V sc2 - The volume of residual gas at ground level under the target exhaust pressure, in ml.

[0178] Similarly, the theoretical output of each other layer can be calculated based on the above steps. Mi is the actual output of each layer (after flow rate conversion), which is measured experimentally. The specific formula is as follows:

[0179] ,

[0180] Among them, M i - Actual output measured in each layer of the experiment, in ml; Q i - Flow rate of each layer measured by mass flow meter, ml / min; t - time, min.

[0181] Subtracting the actual output from the theoretical output of each layer yields the amount of gas entering (leaking) from each layer. The specific formula is as follows:

[0182] ;

[0183] In the formula, is For cross-flow, ml, if >0 indicates the amount of leakage from that layer; if <0 indicates the amount of intrusion into this layer.

[0184] In addition, the extraction degree of a single layer can be calculated. The results are shown Figure 6 The specific formula is as follows:

[0185]

[0186] In the formula: - Single-layer recovery rate, %

[0187] Single-layer output contribution The specific formula is as follows:

[0188]

[0189] In the formula: -Contribution of output per layer, %

[0190] Repeat the above steps to calculate the flow rate at 13 min and 75 min. The specific calculation results are shown in Table 3.

[0191]

[0192] In all the above embodiments, the experimentally measured gas production per layer was greater than the calculated production, indicating that gas had entered the layer; conversely, the experimentally measured gas production per layer was less than the calculated production, indicating that gas had escaped from the layer. The results are shown in [the table below]. Figure 4 .

[0193] The above embodiments are only used to illustrate the technical solutions of the present invention, and are not intended to limit it. Although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features. Such modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. An experimental method for measuring interlayer flow rates in a high-temperature, high-pressure large flat plate model water-transgressive rhythmic gas reservoir, characterized in that, Includes the following steps: Step S1: Determine the pressure and gas saturation of the rock slab using an experimental setup, and calculate the gas production of each sub-layer of the rock slab at each moment using a gas mass flow meter; Step S2: Secure the rubber sleeve containing 480 electrode plates tightly to the rock slab. Then connect the acoustic-electric data acquisition system to the rock slab and the computer. Based on the acoustic-electric data acquisition system, determine the water saturation at 480 points in the gas reservoir. At this point, the gas saturation is: , Step S3: Calculate the gas volume factor: ， In the formula: B gi -Gas volume coefficient under different pressures; Z i -Gas compressibility factor under different pressures; P i - Different pressures; t - Experimental temperature, °C; Psc - Standard atmospheric pressure, MPa; Step S4: Convert the underground gas into the surface gas: ， In the formula: V sci -Ground gas volume under different pressures, ml; HCPV i - Hydrocarbon pore volume under different pressures; Step S5: Sum and average the hydrocarbon pore volume (HCPV) at each point in the single layer to obtain the average hydrocarbon pore volume (HCPV) of that layer, and then combine it with the formula... Calculate the reserves V of each single layer under the target formation pressure. sc1 and remaining reserves V under target abandonment pressure sc2 Subtracting the two yields the theoretical output of a single layer: ， Where: N i - The volume of gas leaving the monolayer at the ground, in ml; V sc1 - The volume of gas at the surface under the target's original formation pressure, in ml; V sc2 - The volume of residual gas at ground level under the target exhaust pressure, in ml; Step S6: Subtract the theoretical production from the actual production for each layer to obtain the gas ingress or egress rate λ for each layer. ， In the formula, λ represents the cross-flow rate, ml. If λ > 0, it represents the outflow rate of the layer; if λ < 0, it represents the inflow rate of the layer. M i Actual yield of each layer as measured by experiments.

2. The experimental method for measuring interlayer flow rates in a high-temperature, high-pressure large flat plate model water-transgressive rhythmic gas reservoir according to claim 1, characterized in that, In step S1, the static parameters of the gas reservoir include pressure, temperature, porosity, permeability, and hydrocarbon pore volume (HCPV).

3. The experimental method for measuring interlayer flow rates in a high-temperature, high-pressure large flat plate model water-transgressive rhythmic gas reservoir according to claim 1, characterized in that, In step S1, the formulas for calculating the actual output measured in each layer of experiments are as follows: ， Among them, M i - Actual output measured in each layer of the experiment, in ml; Q i - Flow rate of each layer measured by mass flow meter, ml / min; t - time, min.

4. The experimental method for measuring interlayer flow rates in a high-temperature, high-pressure large flat plate model water-transgressive rhythmic gas reservoir according to claim 1, characterized in that, In step S3, the calculation steps for the gas compressibility factor are as follows: Step S3.1: Determine the experimental temperature and initial formation pressure. Pressure changes during the experiment can be measured by a pressure sensor. Step S3.2: Calculate the gas compressibility factor under different pressure and temperature conditions: ， The convergence value of Z obtained using the iterative formula is the gas compressibility factor. ， Where: Z - gas compressibility factor; Pr - Gas relative pressure, MPa; T r -Gas relative temperature , ℃; ω - gas eccentricity factor.

5. The experimental method for measuring interlayer flow rates in a high-temperature, high-pressure large flat plate model water-transgressive rhythmic gas reservoir according to claim 1, characterized in that, In step S4, the calculation steps for the average hydrocarbon pore volume (HCPV) of the rock slab are as follows: Step S4.1: The acoustic-electric scanning system has 480 points (12 rows × 40 columns), evenly distributed across the entire rock slab. Based on the dimensions of the rock slab and the length or width of each layer, the number of points evenly distributed across each layer and the size of each point are calculated. Using the following formula, the hydrocarbon pore volume (HCPV) of each point is calculated: ， in, —The volume of hydrocarbons in the pores at the first electrode point; —These are the length, width, and height of the first electrode point, respectively; — represents the water saturation at the first electrode point; —This represents the porosity of the first layer; Therefore, we can conclude that: ， ， Step S4.2: The number of electrodes corresponding to each sublayer needs to be evenly distributed based on the width of each sublayer and the width of the entire rock slab; the length, width, and height of each electrode point are equal, and each electrode point must correspond to the porosity of its layer. The average hydrocarbon pore volume (HCPV) of the entire rock slab is: 。 6. An experimental apparatus for measuring interlayer flow rates in a high-temperature, high-pressure large plate model water-transgressive rhythmic gas reservoir, wherein the apparatus is applied to the experimental method for measuring interlayer flow rates in a high-temperature, high-pressure large plate model water-transgressive rhythmic gas reservoir as described in any one of claims 1 to 5, characterized in that, include: The system includes a fully automatic high-pressure displacement pump, a formation water intermediate container, a water pump, a sapphire gas-liquid separator, a mass flow meter, an acoustic and electrical data acquisition system, and a pressure sensor. The flat plate model contains a rock slab model, an acoustic and electrical scanning device, and pressure measuring points. It has an injection end and an extraction end on both sides. The saturation pipeline port on the left side of the flat plate model is connected to the intermediate container filled with formation water and the water pump to simulate the edge water body. The water intrusion pipeline end is connected to the displacement pump, the formation water pressure vessel, and the gas intermediate container. The extraction end on the right side of the flat plate model is connected to the inlet end of the sapphire gas-liquid separator. The outlet end of the sapphire gas-liquid separator is connected to the mass flow meter. The acoustic and electrical data acquisition system is mounted on the surface of the rock slab.

7. The experimental apparatus for measuring interlayer flow rates in high-temperature, high-pressure large flat plate model water-transgressive rhythmic gas reservoirs according to claim 6, characterized in that, The flat plate model includes a water intrusion pipeline, a saturation pipeline, pressure measuring points, and a production well; the water intrusion pipeline and the saturation pipeline on the left are connected to the corresponding equipment through high-temperature and high-pressure pipelines and valves, respectively; the production end on the right is connected to a sapphire gas-water separation device; the model is connected to an acoustic and electrical data acquisition system, pressure and temperature sensors, a confining pressure pump, and a vacuum pump.

8. The experimental apparatus for measuring interlayer flow rates in high-temperature, high-pressure large flat plate model water-intrusion rhythmic gas reservoirs according to claim 6, characterized in that, The sapphire gas-water separation device mainly consists of a high-pressure gas-water separator and a high-pressure dryer; the produced well is connected to the corresponding high-pressure gas-water separator and high-pressure dryer in sequence through high-temperature and high-pressure pipelines and valves.

9. The experimental apparatus for measuring interlayer flow rates in high-temperature, high-pressure large flat plate model water-intrusion rhythmic gas reservoirs according to claim 6, characterized in that, The high-pressure gas mass flow meter is connected to the outlet end of the corresponding high-pressure drying pipe, and each mass flow meter is connected to the corresponding data acquisition system to monitor the changes in the gas production rate of the single layer in real time.

10. The experimental apparatus for measuring interlayer flow rates in high-temperature, high-pressure large flat plate model water-transgressive rhythmic gas reservoirs according to claim 6, characterized in that, The water simulation device includes a water pump, a water parameter system, a water pressure vessel, and a pressure sensor. The water parameter system is connected to the top of the water pump, and the formation water pressure vessel is connected to the right side. The formation water pressure vessel is then connected to the saturation pipeline of the flat plate model, and the pipeline is equipped with a pressure sensor. Pressure measurement points are set inside the rock slab model, and pressure sensors are connected to the outside of the model.

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