35 results about "Material balance equation" patented technology

The invention relates to the technical field of carbon emission calculation, in particular to an enterprise carbon emission calculation evaluation method and system and a storage medium. The method comprises the following steps: collecting boundary material inflow information and material outflow information of an enterprise production system to obtain material flow data; establishing a material balance equation based on the material flow data, and tracking a flow path of carbon elements through the material balance equation to obtain a carbon element balance table; and according to preset standard state thermodynamic parameters and chemical reaction equations, performing combustion condition and stoichiometric unit fuel combustion on the carbon element balance table to generate carbon emission, and obtaining direct carbon emission data. According to the method, direct and indirect carbon emission and carbon sink contribution are integrated, the total carbon emission of the enterprise is dynamically summarized and counteracted, net carbon emission data are generated, and a quantitative basis is provided for a carbon neutralization target of the enterprise.

The invention discloses an EUR prediction model construction method and system of a tight gas reservoir gas well, and relates to the field of oil and gas field development technology and artificial intelligence cross technology, and the method comprises the steps: collecting multi-source data; screening the multi-source data by adopting a three-level feature screening method, and removing redundant features; constructing a heterogeneous integrated model comprising a plurality of machine learning models, inputting the screened features into the heterogeneous integrated model to carry out EUR prediction, obtaining respective prediction errors of different machine learning models, correcting each EUR prediction result based on the prediction errors in combination with a material balance equation MBE, a yield attenuation model DCA and fracture network simulation, and carrying out EUR prediction. And carrying out weight distribution on each machine learning model after the EUR prediction result is corrected by adopting an error reciprocal weighting method to generate a final combined EUR prediction model. According to the method, an optimization strategy combining data driving and physical constraint is adopted, and the precision and reliability of EUR prediction are improved.

A rapid prediction method for formation pressure of a fractured horizontal well based on production data relates to the technical field of oil and gas development and mainly comprises the following steps: inputting wellhead pressure to calculate well bottom pseudo-pressure at a corresponding moment based on pressure data and seismic data, and calculating daily output and total output of cracks in a formation; selecting the average formation pressure corresponding to a plurality of production moments as a parameter to be optimized, obtaining the optimal average formation pressure corresponding to each production moment through genetic algorithm iteration processing, fitting the original reserves of the gas reservoir, bringing the fitted original reserves of the gas reservoir back to the gas-water two-phase material balance equation, and obtaining the optimal average formation pressure corresponding to each production moment. Obtaining a relation curve of the cumulative gas production of the horizontal well and the average formation pressure for formation pressure prediction; according to the method, data in multiple aspects are integrated, the wellbore flow model and the multi-fracture two-phase productivity model are combined, and the formation pressure continuous prediction without well shut-in is realized through genetic algorithm optimization and a material balance equation, so that the problems that a traditional method depends on a well shut-in test, the calculation is complicated and the adaptability is poor are solved.

The invention relates to a water invasion volume quantitative identification method based on a semi-ellipsoid radial seepage model, and belongs to the technical field of oil reservoir engineering. The method comprises the following specific steps that dimensionless time tD and pressure increment delta pj of an oil well are calculated; calculating dynamic reserves without water invasion according to the dynamic data of the oil well and a flowing substance balance equation; calculating a water invasion coefficient; the water invasion volume is obtained. The invention relates to a novel method for calculating invasion volumes of different types of water bodies invaded into an oil reservoir by radial flow edge and bottom water by utilizing a semi-ellipsoid geometric model of a Van Everdex-Hust equation principle, which can solve the problem of quantification of the invasion volumes of the water bodies at any moment in the water invasion process of the edge and bottom water oil reservoir. The influence of unstable seepage on the water invasion process is considered, the basic law of fluid flowing in the water invasion process is met, meanwhile, the water invasion coefficient calculation method which does not need to estimate the size of an oil reservoir is provided, and the overall error is small.

The invention discloses a method and a device for determining an oil reservoir numerical simulation analysis water body. The method comprises the following steps: establishing an unsteady-state plane radial flowing water invasion equation of liquid in an elastic medium; establishing a material balance equation; substituting the unsteady plane radial water invasion equation into the material balance equation, recording time, calculating to obtain dimensionless water invasion, and calculating to obtain dimensionless time; calculating the original water body volume; calculating a water invasion speed, and calculating a water invasion water production index based on the water invasion speed; the method comprises the following steps: calculating a numerical simulation prediction result, assigning the numerical simulation prediction result to an AQUFETP keyword for analyzing a water body, carrying out reservoir production history fitting, and carrying out proper adjustment according to the numerical simulation prediction calculation result until the required fitting precision is reached. According to the method, the oil reservoir numerical simulation historical fitting debugging workload is reduced, and the reliability of a water fitting result is improved.

The application provides a water invasion amount identification method, system, device and medium in the production process of a water and gas reservoir well, comprising the following steps: establishing a corresponding equivalent water invasion model based on the relative position relationship between the water area and the gas area of the reservoir well; establishing a water invasion material balance model according to the stage division of the equivalent water invasion model and the pressure measurement time points in previous years; iteratively calculating the water invasion material balance model based on the principle that the stage water area pressure linearly decreases according to the stage water invasion amount; and evaluating the water body drainage line and guiding the drainage gas production of the reservoir well based on the iteratively calculated water invasion material balance model. The application selects the equivalent water invasion model corresponding to different well production geological models, establishes an iterative algorithm meeting the gas and water flow material balance equation, obtains well historical pressure parameters and reservoir parameters, calculates the current water invasion amount, and is further used for evaluating the water body and guiding the drainage gas production of the gas field well. The application can simplify parameters, avoid the situation that the crack water invasion model in the prior art cannot accurately depict and has difficulty in multi-parameter representation.

A method for determining well wall collapse of a single well for a fractured-vuggy reservoir is provided. The method includes following steps: S1, treating the single well of the fractured-vuggy reservoir as an isolated reservoir; S2, calculating a water influx rate for the fractured-vuggy reservoir; S3, substituting a formula of the water influx rate into a material balance equation; S4, calculating a change of an oil productivity index without considering the well wall collapse; S5, establishing an optimizing model for obtaining the oil productivity index; S6, calculating the formation pressure at any time in production through step S3; S7, calculating the oil productivity index at any time through the formation pressure, and establishing an optimal objective function; and S8, calculating a difference between the oil productivity index at any time and the theoretically calculated oil productivity index at any time, and determining whether the difference meets an accuracy requirement.

The application provides a gas reservoir well group intercommunication evaluation method; comprising: step one, establishing a multi-well group supply gas reservoir material balance mathematical model; step two, a well group inter-supply gas amount calculation method; step three, model solving, obtaining each time step zone formation pressure solution; step four, after solving the formation pressure of each block at different time steps by step three, the particle swarm optimization algorithm is used to inverse each block reserves and the parameters between well groups, so that the calculated formation pressure is consistent with the actual monitoring value. The application introduces the inter-well group conductivity to consider the channeling between well groups, deforms the gas reservoir material balance equation with supply, establishes a multi-well group material balance calculation mathematical model, solves the model by using successive substitution, Newton-Raphson nonlinear iteration algorithm and the like, combines the particle swarm algorithm, fits the formation pressure, inverses the dynamic control reserves and the inter-well group conductivity, and forms a gas reservoir well / inter-well group intercommunication evaluation method.

The present invention provides a method for estimating the outlet density of a multi-effect countercurrent evaporation process considering time correlation, which relates to the technical field of outlet density estimation. By constructing a dynamic mechanism model of a five-effect and five-flash countercurrent evaporation process, including material balance equations, heat balance equations and steam temperature calculation equations for evaporation units and flash units; selecting input variables, based on an intelligent optimization algorithm, and combining the variable dependence constraints of adjacent time points, solving the unknown variables in the dynamic mechanism model; using the solution results of the previous moment to constrain the value range of variables at the current moment, realizing continuous and smooth estimation of the outlet density. It effectively reduces the errors caused by mutation data or outliers, thereby making the density estimation of the whole process more accurate and reasonable.

This invention relates to the field of petrochemical production technology, and more particularly to a method, device, electronic equipment, storage medium, and computer program product for production operation management and control of a crude oil industry chain. The method includes: constructing a material balance equation and an objective function for the material balance equation based on the logistics balance of crude oil and refined oil in the production operation of the crude oil industry chain; determining the imbalance data in the crude oil industry chain based on the objective function and the material balance equation; determining the material loss nodes in the production operation of the crude oil industry chain based on the imbalance data; and optimizing the material loss nodes in the production operation of the crude oil industry chain. The daily material balance results of this invention can also provide basic data for risk simulation and production operation scheduling for the next day, thereby meeting the needs of risk prediction and early warning, scheduling and operation optimization in production operation management, and improving the comprehensive management and control capabilities of production operation.

The invention discloses an iterative calculation method for determining dynamic reserves after fracture closure of a fault control fracture-vuggy oil reservoir, and the method comprises the following steps: S1, obtaining cumulative production data and flowing pressure data of a target well, and drawing an energy indication curve according to the cumulative production data and the flowing pressure data, dividing the energy indication curve into a stage I before crack closing and a stage II after crack closing according to slope change; s2, establishing a material balance equation, wherein a comprehensive compression coefficient in the material balance equation adopts a modified comprehensive compression coefficient which considers fluid item change and reservoir physical property parameter change at the same time; s3, collecting physical property parameters of the reservoir and the fluid of the target well, and performing iterative calculation in combination with a material balance equation; and S4, selecting a result with a minimum error as a dynamic reserve result of the stage II according to an iterative calculation result. According to the method, the dynamic reserves after the fracture is closed can be more conveniently and effectively obtained, meanwhile, the change of the porosity of the well control area caused by fracture closing can be evaluated, and reliable support is provided for dynamic analysis and efficient development of oil reservoirs of the type.

The application discloses a silicon-iron alloy high-load dynamic adjustable potential evaluation method, which comprises the following steps: for a smelting process, a production-carbon mapping equation is constructed; for a raw material preparation and pouring process, an electricity-production mapping equation of the raw material preparation and pouring process is established; for the smelting process, an electricity-carbon-production space-time alignment model is constructed, and corresponding alignment data are obtained; for the raw material preparation and pouring process, electricity-production space-time alignment models are respectively constructed, and corresponding alignment data are obtained; a trained gated graph convolutional neural network adaptively identifies time-varying working condition parameters under different working conditions; according to the time-varying working condition parameters, a silicon-iron alloy electricity-carbon-production multi-dimensional matrix mapping model is constructed through a first-order electrothermal balance function and a material balance equation of a submerged arc furnace; an electricity-carbon-production coupling constraint set is constructed; and a silicon-iron alloy load elastic adjustment safety feasible region is depicted according to the electricity-carbon-production coupling constraint set and the silicon-iron alloy electricity-carbon-production multi-dimensional matrix mapping model.

The invention provides a method for calculating the dynamic reserves of a fractured-vuggy carbonate reservoir, and the method comprises the steps: a production well of the fractured-vuggy carbonate reservoir carries out gas injection oil replacement production, and the gas injection oil replacement production comprises a natural energy development stage and a gas injection oil replacement development stage; according to the elastic energy of the natural energy development stage and the elastic energy of the gas injection oil replacement development stage, material balance equations of the natural energy development stage and the gas injection oil replacement development stage are established respectively, and then according to actual production data, PVT parameters and the material balance equations of a production well, the dynamic reservoir reserves and the water volume are comprehensively solved. According to the calculation method, based on the elastic energy of the oil reservoir, the material balance equation is established, the dynamic reserves and the water volume of the oil reservoir can be solved according to a small amount of actual production data, the calculation method is simple, the calculation result is accurate, and the calculation method is suitable for the complex fracture-vuggy carbonate reservoir, especially the reservoir containing bottom water.

The invention provides a method, system, equipment and medium for calculating the water invasion amount of a fault-control fracture-vuggy carbonate reservoir, and the method comprises the steps: 1, calculating the water invasion amount of the fault-control fracture-vuggy carbonate reservoir according to the obtained oil well output volume of a stable production stage before water invasion, the formation pressure of the stable production stage before water invasion, the formation pressure during water invasion and the output volume after water invasion; calculating to obtain the theoretical liquid production capacity driven by the external water body after water invasion; 2, according to the obtained actual formation pressure after water invasion, the water body volume of formation pressure change caused by water invasion is obtained through calculation; 3, according to the obtained theoretical liquid production capacity driven by the external water body after water invasion and the water body volume of the formation pressure change caused by water invasion, the water invasion amount after water invasion is obtained through calculation; according to the method, the material balance equation is applied, only the fluid property and the pressure change of the fluid in the reservoir container are considered, and the use of parameters which are difficult to accurately obtain is avoided, so that the accuracy and credibility of a calculation result are relatively high.

The present invention provides a method for determining the pressure drive injection allocation volume of an injection well, including: Step 1, calculating the relationship between the injection volume and the formation pressure recovery using the material balance equation; Step 2, drawing a chart of the formation pressure drop variation at different injection-production ratios based on Step 1; Step 3, drawing a profile of the inter-well pressure variation before pressure drive; Step 4, determining the ultimate easy-flow radius of the water well and the ultimate oil drainage radius of the oil well during pressure drive; Step 5, drawing a schematic diagram of the water drive swept area between the oil well and the water well during pressure drive, and calculating the maximum water drive front swept radius corresponding to the establishment of an effective displacement relationship using the fluid connection method; Step 6, calculating the pore volume within the water drive swept radius using the ellipsoid model to determine the pressure drive injection volume; Step 7, comparing and optimizing the pressure drive water volume calculated in Step 6 with the material balance method to determine the appropriate displacement radius and pressure drive injection allocation volume. This method determines the pressure drive injection front and thus the pressure drive injection volume according to the seepage characteristics of low-permeability reservoirs and in combination with the inter-well pressure variation characteristics.

The present application relates to a kind of thick sandstone reservoir gravity gas drive productivity prediction method, device, medium and equipment, method includes the following steps: with the Dietz model of inclined gas cap reservoir gas drive oil as the basis, longitudinal with gas-oil displacement front as limit the entire thick sandstone reservoir is divided into unsaturated zone and saturated zone, the volume of remaining oil, residual oil and oil film in two regions is analyzed and calculated, with material balance equation and Jeffreys equation as the basis, material balance relationship is established;Based on material balance relationship and Darcy percolation formula, establish thick sandstone reservoir gravity gas drive productivity prediction mathematical model 1;Combining Kozeny formula, oil and gas J function, establish thick sandstone reservoir gravity gas drive productivity prediction mathematical model 2;Based on mathematical model 1 and mathematical model 2, the size of thick sandstone reservoir gravity gas drive productivity at any time is calculated.The method greatly improves the practicability of thick sandstone reservoir gravity gas drive productivity calculation model.

The present application relates to a kind of oil ring condensate gas reservoir oil-gas interface migration distance determination method and device, the method comprises: establishing the material balance equation of oil ring condensate gas reservoir;Wherein, material balance equation is by the influence of gas cap anti-condensation factor, oil ring dissolved gas factor, reservoir rock expansion factor and water vapor content factor in the process of oil ring condensate gas reservoir gas cap and oil ring cooperative exploitation is established;Based on the obtained reservoir geologic feature parameter, development dynamic data and material balance equation, the oil-gas interface migration distance of different time under different oil-gas cooperative exploitation mode is determined.The present application can describe the oil-gas interface migration law of oil ring condensate gas reservoir, so as to determine the reasonable oil ring condensate gas reservoir development mode according to the oil-gas interface migration law of oil ring condensate gas reservoir, it is of great significance for preventing oil-gas crossflow, keeping oil-gas interface stable and maximum limit exploitation gas cap and oil ring resource.

The application discloses a kind of based on dynamic leak-off volume superposition's three-dimensional fracturing well interference prediction method, it is related to unconventional oil and gas field development technical field.The application is based on dynamic leak-off volume method first to establish single well oil-water two-phase productivity prediction model, then the single well oil-water two-phase productivity prediction model is expanded, the fluid transport equation set and material balance equation set between adjacent two production wells are obtained, and multi-well oil-water two-phase productivity prediction model is constructed, combined with actual multi-well system, the multi-well oil-water two-phase productivity prediction model is used to simulate the interference between multi-fracturing wells, the reservoir production dynamic simulation result is obtained and compared with the simulation result of CMG reservoir numerical simulation software, to verify the accuracy of the multi-well oil-water two-phase productivity prediction model prediction.The application realizes the accurate prediction of the interaction and interference intensity of the fluid in the multi-well system, improves the simulation accuracy and operating efficiency of the interwell fluid, and is beneficial to guide well pattern optimization design and oil and gas exploitation.

The invention provides a constant-volume gas drive gas reservoir reserve and productivity evaluation method based on production dynamic data. The method comprises the steps that according to gas reservoir basic parameters, actually-measured gas well daily gas production and actually-measured flowing bottomhole pressure dynamic data, the correlation between a gas coefficient and pressure is constructed; performing derivation and linearization processing on the material balance equation of the gas reservoir and the gas well exponential productivity equation according to the correlation to obtain a gas reservoir flowing material balance linear equation; according to a gas reservoir flowing substance balance linear equation, circularly calculating transverse and longitudinal axis dynamic data; drawing a scatter diagram according to the transverse and longitudinal axis dynamic data, and fitting scatter points in the scatter diagram by adopting a linear function to obtain a slope of a fitting straight line; calculating single well control reserves according to the gas reservoir basic parameters and the slope of the fitting straight line; and simultaneous solving is carried out on the fitting straight line and the index and the coefficient of the gas well exponential productivity equation, and the gas well productivity equation is obtained. According to the method, the theoretical relationship among the parameters is established, the problem of multiplicity of solutions is avoided, and the calculation precision is improved.

The application discloses a method for simulating the variable well storage effect caused by downhole throttling of a gas well, which comprises the following steps: step 1) establishing a dimensionless wellbore material balance equation under downhole throttling conditions to obtain a dimensionless pressure value under the downhole throttling conditions; step 2) drawing a double-log pressure derivative curve chart based on the dimensionless pressure value in step 1) to simulate the variable well storage effect under different parameter combinations under the downhole throttling conditions; and step 3) making a normalized pseudo-pressure difference and its derivative and a measured curve chart of the shut-in time based on actual pressure buildup data under the throttling conditions, and drawing the measured curve chart on the double-log pressure derivative curve chart in step 2) to keep the measured curve chart coinciding with the double-log pressure derivative curve chart, and solving relevant parameters of the variable well storage stage according to a fitting key point, so that the variable well storage effect caused by the downhole throttling of the gas well is described through the relevant parameters.

A material balance-based method for evaluating the effectiveness of volumetric fracturing in unconventional reservoirs is proposed. First, a set of material balance equations for volumetric fracturing in unconventional reservoirs is established. Then, by designing a calculation process and developing a multi-well synchronous solution program, key evaluation parameters for the volumetric fracturing effect of each well are obtained. Finally, the proportion of injected fluid in each volume during the volumetric fracturing process is quantitatively analyzed, resulting in theoretical charts of volumetric fracturing effect evaluation parameters under different construction parameters. Taking a typical well group in an actual unconventional reservoir block as an example, the volumetric fracturing effect at different well network development stages is quantitatively evaluated. This method, based on material balance, offers a simple parameter input and calculation process, and can provide timely guidance for well network adjustments and comprehensive management of unconventional oil and gas reservoirs.

The invention belongs to the technical field of intelligent control, and particularly discloses a steam pipe network optimization control method and system based on multi-level cooperative control. The control method comprises the following steps that a material balance equation is built based on the steam input flow, the steam output flow, the opening degree of a pressure reducing valve and the emptying amount of a pipe network of each pressure grade; determining a dynamic response model of the opening degree of the pressure reducing valve to the pipe network pressure through the historical operation data; constructing a target function by taking minimization of the total opening of the emptying valve as a target, setting constraint conditions based on the material balance equation and the dynamic response model, calculating to obtain the steady-state optimal valve opening of each valve, and controlling each valve according to the steady-state optimal valve opening; if it is monitored that the load suddenly changes, the optimal steady-state opening degree of each valve serves as a reference target, the priority weight is determined in combination with a dynamic response model, and control is conducted according to the priority; and if the communication state of the APC instruction and the DCS system is abnormal, automatically switching to a DCS manual mode. The pressure stability is improved, and the system safety is guaranteed.

The application discloses a physical-data collaborative driving unconventional gas well production prediction method and system, and the method comprises the following steps: S1, obtaining production data of a target unconventional gas well, and preprocessing the production data; S2, based on a dynamic drainage area calculation model and a material balance equation coupled with the dynamic drainage area, a target function is established with the minimum cumulative production error as the target; S3, history matching is carried out to obtain model parameters; S4, the average pressure of the dynamic drainage area at different times is calculated; S5, the corresponding gas production index of the gas well at different times is calculated; S6, a gas production index-material balance pseudo-time curve is drawn, and a characteristic straight line is obtained; S7, the slope and the slope distance of the characteristic straight line are used to obtain fitting parameters; and S8, the gas production index corresponding to any time tj is calculated, and production prediction is carried out based on the recursion principle. The application realizes physical-data collaborative driving unconventional gas well production prediction, and can provide technical support for unconventional gas well development.

This invention relates to the chemical industry and discloses a simulation and analysis method for the polyester falling film viscosity-enhancing reaction process. This invention employs an interactive method combining numerical calculation and process simulation software to establish a model of the polyester falling film viscosity-enhancing reaction process. By utilizing physical equations such as reaction kinetics, mass transfer kinetics, and fluid kinetics, the material balance equations for the polyester falling film viscosity-enhancing process are decoupled and calculated. This effectively and conveniently obtains the distribution of basic physical quantities (such as intrinsic viscosity, molecular weight, and terminal carboxyl group content) of the polyester falling film reaction process, thus providing excellent guidance for experimental research and industrial design. Furthermore, the simulation and analysis method for the falling film viscosity-enhancing reaction process proposed in this invention has a certain degree of versatility and can be applied to the simulation of various polyester falling film melt polycondensation reaction processes.

The invention discloses a method and device for determining oil reservoir reserves by using well bottom fluid density, and the method comprises the steps: determining the relation between the original volume of an oil reservoir and the volume of crude oil and water under the initial condition of the oil reservoir; based on a material balance equation, a well bottom multiphase fluid density model is established according to the relation between the original oil reservoir volume and the crude oil volume and the water volume; when the oil reservoir pressure is higher than the bubble point pressure, relevant parameters of at least two tests are obtained; and according to the related parameters and the well bottom multiphase fluid density model, determining the oil reservoir reserves.

The invention provides a method and a system for rapidly predicting the gas-water two-phase yield of a compact water-containing gas reservoir fractured well, and the method comprehensively considers the influence of the slippage effect, the stress sensitive effect, the starting pressure gradient and the gas high-pressure physical property of gas phase seepage in a compact reservoir on a seepage mechanism. Respectively establishing gas phase correction pseudo-pressure and pseudo-time and water phase correction pseudo-pressure and pseudo-time to realize linear processing of nonlinear factors, and determining a two-phase unsteady-state seepage model; processing model parameters by adopting implicit pressure and explicit saturation, and deducing a corresponding analytical solution; determining a tight reservoir utilization range, and establishing a corresponding gas-water two-phase material balance equation for resolving average formation pressure and average water saturation to update seepage model parameters; therefore, the two-phase yield prediction of the tight reservoir in the full life cycle is realized. According to the scheme, the problems of insufficient calculation precision and low efficiency in the prior art can be solved, accurate and rapid prediction of the two-phase yield of the tight gas fractured well is achieved, and technical support is provided for efficient development of a tight water-containing gas reservoir.

The invention provides a method for dynamically predicting the productivity of a fault-solution condensate gas well, and relates to the technical field of condensate gas reservoir development, and the method comprises the steps: building a material balance equation of a target fault-solution condensate gas reservoir based on a molar weight balance principle; constructing a binomial productivity equation of the target broken-solution condensate gas reservoir; and on the basis of the material balance equation and the binomial productivity equation, in combination with the wellbore flow equation, obtaining a dynamic productivity prediction result of the target fault solution condensate gas reservoir. The method for dynamically predicting the productivity of the broken-solution condensate gas well can be suitable for any period of gas reservoir development. According to the method, dynamic and static data are comprehensively utilized, the gas well productivity is predicted in real time based on gas well dynamic production data, and the method has the advantages of being solid in theoretical basis, high in systematicness, simple, easy to use, clear in result and the like.

This invention provides a data-based environmental analysis method and system for chemical equipment. The method uses material balance equations to verify the consistency of operating data, environmental emission data, and material consumption data of chemical equipment, eliminating unreliable data and obtaining a reliable data stream. By dynamically calculating the fusion weights of the reliable data stream based on operating conditions, it solves the problem that static weighting cannot adapt to fluctuations in operating conditions. By using a long short-term memory network for early prediction, calculating the posterior probability of the cause using a structural causal model and combining it with counterfactual adjustment, the adjusted features are re-input into the long short-term memory network to verify the hypothesis, thus solving the problems of delayed pollution early warning and ambiguous source location in existing technologies for chemical equipment.

The invention discloses a gas storage geologic body rock compression coefficient determination method, device, equipment and medium, and the method comprises the steps: obtaining stratum data and historical production data corresponding to a target gas storage geologic body, the stratum data comprising original stratum pressure data and stratum temperature data; the historical production data comprises accumulated gas production rate; determining the geologic body water storage amount corresponding to the target gas storage geologic body according to the stratum data and the historical production data; and determining a compression coefficient corresponding to the target gas storage geologic body based on the geologic body water storage amount and the gas storage geologic body material balance equation. Based on the technical scheme, the geologic body water storage amount is determined according to the stratum data and the historical production data corresponding to the target gas storage geologic body, and the compression coefficient is rapidly determined according to the geologic body water storage amount and the gas storage geologic body material balance equation, so that the compression coefficient of the gas storage geologic body can be rapidly and accurately calculated; and the calculation efficiency of the compression coefficient is improved.

The invention discloses a shale formation inter-well interference determination method and system and a storage medium, and belongs to the technical field of shale formation inter-well interference identification testing. The measurement method at least comprises the following steps: acquiring original inter-well data and processing the original inter-well data to obtain available inter-well data; establishing a pressure interference model based on a linear flow formula and a material balance equation; and inputting the available inter-well data into the interference model to determine the inter-well interference. The original inter-well data at least comprises fracture parameters, formation pressure, bottom hole pressure, well gas yield, inter-well permeability and well depth. The interference model based on the linear flow formula and the material balance equation is constructed, the calculation process is simple, and the calculation result is accurate; the processed inter-well monitoring data is optimized and solved by using a pressure interference model, so that the interference degree between different wells can be quantitatively evaluated, and the source and action mechanism of interference can be accurately judged; the method is simple and easy to implement, and the obtained result is high in accuracy.