67 results about "Reservoir type" patented technology

The invention belongs to the technical field of oilfield development, and discloses an oil and gas reservoir modeling processing system based on clastic rocks and a use method of the oil and gas reservoir modeling processing system. The data processing system is used for processing fault and logging data, geological stratification data and well perforation data, the grid management system is used for dividing and encrypting grid types, the model building system is used for building a digital-analog model and an oil-gas reservoir relation model, and the digital-analog management system is used for outputting the built model. And the established digital model is convenient to modify and reconstruct, so that the digital model pretreatment work requirement of complex oil and gas reservoir types is met, the historical fitting speed of subsequently realizing numerical simulation is improved, and the modeling treatment of clastic rock oil and gas reservoirs is facilitated.

The invention discloses a complex riverway geologic modeling method based on automatic pickup of multiple object source directions, and belongs to the technical field of oil-gas exploration and development, and the method comprises the following steps: S1, obtaining the plane and longitudinal distribution characteristics of a riverway; s2, establishing a three-dimensional space distribution model of the river channel body in different periods, and processing boundary data of the river channel in different periods; s3, calling azimuth angle data to establish a sand body distribution model in the river channel in different periods; s4, single well reservoir types are divided, and reservoir type distribution models in the river channels in different periods are established; and S5, discretizing the porosity curve of the single well, calling azimuth angle data to establish porosity models under different reservoir types, and establishing permeability models under different reservoir types. According to the built river channel sand body and physical property parameter model, the situation that reservoir physical property distribution is controlled by river flow direction variability material sources is truly represented, the method is suitable for scenes with large work areas and complex river channel distribution, and modeling timeliness and accuracy can be improved.

The present application relates to a kind of thin interbed type deposit high-quality reservoir prediction method, comprising: obtaining the geological data, seismic data and well logging data of the region to be analyzed, well seismic combination tracking interpretation oil group top, bottom interface;With the oil group top, bottom interface as constraint, utilize the three-dimensional seismic data acquisition three-dimensional seismic inversion data;With the oil group top, bottom interface as constraint, according to the three-dimensional seismic inversion data and the well logging data are combined, obtain oil group internal relative isochronous sedimentary interface;According to the oil group internal relative isochronous sedimentary interface, based on three-dimensional seismic inversion data, each small layer reservoir plane distribution in oil group is solved;According to the three-dimensional seismic inversion data, based on the information of actual drilling well, sandstone probability body seismic data is solved;Utilize actual drilling well information to construct reservoir classification standard, realize single well reservoir type division;According to the sandstone probability body seismic data, with single well reservoir type as constraint, carry out high-quality reservoir space distribution prediction.

This application provides a method and apparatus for seismic physical simulation of reservoirs. The method includes: fabricating a corresponding reservoir physical model based on the obtained reservoir type to be simulated; preparing an oil-water emulsion in a corresponding proportion based on the obtained oil saturation to be measured; immersing the reservoir physical model in the oil-water emulsion and using a vacuum method to ensure that the reservoir physical model is fully filled with the oil-water emulsion to obtain a saturated reservoir physical model; encapsulating the saturated reservoir physical model in an epoxy resin layer to form a seismic physical model; immersing the seismic physical model in a pre-set water tank and acquiring seismic experimental data; and selecting target characterization attributes sensitive to oil saturation from the seismic experimental data. This allows for the acquisition of seismic experimental data corresponding to different oil saturations in the reservoir, and further optimization of target characterization attributes sensitive to oil saturation.

This invention discloses a method and system for predicting reservoir types, comprising: obtaining a cross-interpretation chart of sandstone and mudstone transverse and longitudinal wave impedances based on the lithological distribution information, P-wave impedance curves, and S-wave impedance curves of the target layer in the target well; constructing new elastic impedance curves for distinguishing sandstone and mudstone based on P-wave and S-wave characteristics using principal component analysis based on the sandstone and mudstone transverse and longitudinal wave impedances in the cross-interpretation chart; constructing a new three-dimensional elastic impedance data volume based on the new elastic impedance curves and the three-dimensional inversion data volume of transverse and longitudinal wave impedances; and predicting the reservoir type of the entire well section of the target well based on the new three-dimensional inversion data volume of elastic impedances. This invention can construct elastic impedance attributes more suitable for reservoir identification based on transverse and longitudinal wave impedances, and can realize reservoir interpretation using a single parameter, overcoming the problem of low sandstone identification accuracy under impedance overlap, and improving the accuracy and efficiency of sandstone reservoir identification.

The application provides a method and system for calculating the conductivity of a sand-acid fracturing reservoir simulation system, which comprises the following steps: constructing a simulation parameter combination set around sand-acid fracturing operation parameters for reservoir types with sand-acid fracturing requirements; analyzing fracture acid erosion data of different reservoirs by using a preset fracture acid erosion calculation model, and analyzing the embedding depth and deformation data of the proppant in combination with the injection rate parameters and the proppant data; further analyzing the sand concentration of sand-acid fracturing, and setting a rough body simulation distribution coefficient in combination with the injection rate, so as to form a reservoir fracture model that presents a real fracturing state; analyzing the permeability state of the reservoir fracture model after fracturing based on the rough body simulation distribution coefficient and the reservoir closure pressure; and further calculating the corresponding conductivity in combination with the fracture width calculated according to the fracture acid erosion data, the embedding depth and deformation data of the proppant. The method solves the problem that the sand-acid fracturing conductivity cannot be quantitatively analyzed, and provides support for field acid fracturing design and productivity prediction.

The invention discloses a bottom water oil and gas reservoir horizontal well yield increase and water control method, and relates to the field of bottom water oil and gas reservoir development, the method comprises the following steps: dividing land and offshore scenes through multi-scene reservoir parameter dynamic coupling, and obtaining comprehensive coupling parameters through parameter normalization and dynamic weight calculation; in combination with perforation-fracturing parameter mutual feedback, construction parameter adaptation is achieved through multi-parameter linkage calculation; a high-yield water section is identified through distributed optical fiber sensing, and a degradable plugging agent is directionally injected to complete meter-scale segmented water control; matching a productivity prediction sub-model corresponding to the oil reservoir type, and optimizing the prediction precision through deviation correction; production data is collected based on dual-mode transmission, a regulation and control instruction is generated through processing and fusion, period optimization is carried out, and a closed-loop regulation and control system is formed. Meanwhile, an emergency treatment and recovery process is set, and construction safety is guaranteed. According to the method, core technologies such as dynamic coupling, parameter mutual feedback and accurate water control are integrated, and the problems that bottom water coning is fast, yield increasing and water control collaboration is poor, and cross-scene adaptation is insufficient are solved.

This invention discloses a method, system, and medium for optimizing parameters of complex tight oil and gas reservoirs. The method includes: determining reservoir sections based on logging curves; selecting test sections based on these sections; obtaining the number, location, and calcium content of natural fractures based on the logging and imaging curves of the test sections; classifying reservoir types according to the number, location, and calcium content of natural fractures; including porous reservoirs, fractured reservoirs, and mixed reservoirs; determining perforation locations using different perforation determination methods for different reservoir types; optimizing the scale of proppant addition and fluid usage using different stimulation techniques and parameters; optimizing the pump sequence using different fracturing methods; and completing the proppant addition and fluid usage in stages. This invention overcomes the problems of abnormal construction and poor matching between fracturing parameters and reservoir conditions in conventional proppant fracturing methods in complex reservoirs, enabling full utilization of complex reservoirs and increasing single-well production.

The invention discloses a method and system for judging the type of an oil and gas reservoir, and the method comprises the steps: calculating a plurality of component content characteristic indexes at different positions according to the logging gas logging distribution data of a test well in a target work area; according to the multiple component content characteristic indexes, constructing an oil and gas reservoir type identification chart; and according to the actual drilling gas logging value of the drilling well or the drilling well to be completed in the target work area, the oil and gas reservoir type identification chart is utilized to determine the oil and gas reservoir type of the corresponding position. The accuracy of determining the type of the oil and gas reservoir before well completion is improved.

This invention provides a method and application for reservoir type classification, evaluation, and production capacity prediction, relating to the field of oil and gas development technology. The method includes the following steps: obtaining geological and engineering characteristic parameters of the study wells in the block; based on the aforementioned geological and engineering characteristic parameters, statistically determining the maximum and minimum values ​​of each parameter of the study wells in the block, and normalizing all parameter data; establishing a multi-level evaluation system for factors affecting horizontal well reservoirs using the modified hierarchical method, establishing reservoir classification standards, and dividing the reservoirs; and establishing a reservoir stimulation production capacity prediction model using the modified hierarchical method. This method can quantitatively evaluate the fracturing development effect of horizontal wells and guide well and section selection for stimulation. This method has advantages such as simple calculation and strong operability, and has broad application prospects, playing an important guiding role in fracturing optimization design.

This invention belongs to the field of shale oil production prediction technology, and discloses a method for shale oil production prediction and parameter optimization based on physical information constraints. It constructs a training database by designing samples using Latin hypercube sampling and simulating them using an integrated geological engineering model. A neural network model integrating physical information constraints is built, including a fracture volume prediction model and a production prediction model, and trained by combining data-driven loss and physical law loss in the loss function. Using the trained model as a surrogate model, and combining it with the NSGA-II multi-objective optimization algorithm, iterative optimization of fracture volume, single-well production, and net present value of the entire area is performed in three levels to obtain differentiated fracturing operation parameter schemes for different reservoir types. This invention effectively improves the accuracy and physical interpretability of production prediction under small sample conditions, and can efficiently optimize fracturing parameters, significantly improving the economic benefits of shale oil extraction.

The invention relates to a method for identifying a clastic rock low-resistivity oil layer in a salt lake sedimentary environment, and belongs to the technical field of oil exploration and development. The identification method for the clastic rock low-resistivity oil layer in the salt lake sedimentary environment comprises the following steps: determining an identification standard of a dry layer and a production layer in a target layer of a research area based on a corresponding relation of porosity data, permeability data and reservoir types of the target layer encountered by a standard well in the low-resistivity research area; based on the corresponding relation of the irreducible water saturation, the movable water saturation and the reservoir type of the standard well drilling encountering target layer in the research area, the identification standards of the oil layer, the same oil-water layer and the water layer in the production layer in the target layer in the research area are determined. According to the method for identifying the clastic rock low-resistivity oil reservoir in the salt lake sedimentary environment, the reservoir seepage characteristics are considered, the Archie formula is corrected, and the movable water saturation is introduced, so that the identification accuracy of the low-resistivity oil reservoir can be effectively improved.

The invention belongs to the technical field of underground gas storage water invasion amount calculation, and discloses a gas cap reservoir type gas storage multi-cycle dynamic water invasion amount calculation method and a gas cap reservoir type gas storage multi-cycle dynamic water invasion amount calculation system. The method comprises the following steps: establishing a total substance amount conservation equation based on a multi-cycle fluid injection and production change rule of the gas cap reservoir type gas storage; deriving to obtain calculation equations of the amount of original formation fluid substances, the amount of extracted formation fluid substances, the amount of injected natural gas substances and the amount of residual formation fluid substances, and substituting the derived calculation equations into the total substance amount conservation equation to establish a dynamic water invasion amount calculation model; and the formation fluid high-pressure physical property, the reverse condensation liquid saturation degree and the natural gas deviation factor change rule in the multi-period injection and production process are obtained, and the multi-period dynamic water invasion amount is obtained through calculation. The calculation result is high in accuracy, the calculation process is simple, and the method can be suitable for the condensate gas cap reservoir type gas storage where a general material balance method is not suitable.

The embodiment of the invention provides a compact conglomerate reservoir identification method and system, and belongs to the field of unconventional oil-gas exploration and reservoir transformation. The method comprises the following steps: acquiring logging data of a reservoir section to be identified, and preprocessing the logging data; calling a corresponding lithology identification model based on the preprocessed logging data, and determining a conglomerate identification result of the corresponding reservoir section based on the lithology identification model; wherein the lithology identification model is obtained based on BP neural network training; based on the conglomerate identification result, corresponding compact conglomerate reservoir type matching is carried out in a pre-constructed compact conglomerate reservoir type library; and outputting a compact conglomerate reservoir identification result of the reservoir section to be identified based on the matched compact conglomerate reservoir type. According to the scheme, the method can effectively support the fracturing transformation decision of the reservoir, the development strategy is optimized, the oil and gas exploitation risk is reduced, and the production efficiency is improved.

This invention discloses a method, system, electronic device, and computer-readable storage medium for evaluating the sidetracking potential of different types of reservoirs in complex fault blocks. The method includes: determining the reservoir type; selecting evaluation indicators affecting the sidetracking potential of different reservoir types; establishing the weights of each evaluation indicator; determining the distribution of evaluation levels and the corresponding evaluation classification standards for each evaluation indicator in each evaluation level; establishing an unknown single-indicator measurement function; statistically analyzing the actual values ​​of each evaluation indicator for the target reservoir; determining the quantitative value of a single indicator; classifying the sidetracking potential levels based on the comprehensive evaluation of multiple indicators; and calculating the comprehensive score based on the comprehensive evaluation vector of multiple indicators and the assignment of evaluation space. This invention proposes the concept of evaluating sidetracking potential by reservoir type, accurately characterizing the size of the sidetracking potential of the target area, and compensating for the inaccurate potential evaluation when using the same parameters for reservoirs with different conditions; it also establishes an unknown single-indicator measurement function, realizing the hierarchical and quantitative analysis of geological parameters in the target area.

The invention relates to an energy storage refracturing process parameter design method for an integral block. The method comprises the following steps: S1, acquiring basic data of the integral block; s2, determining geological main control factors influencing the productivity according to the reservoir physical property data; s3, establishing a reservoir geologic model by using the basic data in the step S1, and dividing different reservoir types by using geologic main control factors; s4, for each reservoir type, a nine-point water injection development well group is selected, and the optimal water drive front position is determined; and S5, according to the optimal water drive front edge position in the step S4, fracturing parameters are optimized by taking well group productivity as a target. According to the method, the problem that water injection energy storage parameter and hydraulic fracturing parameter optimization methods are lacked in the energy storage and refracturing process of the whole block of the low-permeability reservoir is solved, the pertinence is higher, and refined optimization of different types of reservoirs of the whole block is achieved.

This invention relates to a method for quantitatively evaluating the degree of water intrusion in a gas reservoir, comprising the following steps: identifying the geological structure and reservoir physical properties of the water-intruded gas reservoir; collecting outcrop samples from the corresponding target reservoir; deploying monitoring sensors at key points of the simulated samples; encapsulating the protective layer and pre-embedding the simulated injection wellbore, as well as prefabricating the gas reservoir injection well and production well; analyzing formation water saturation in the servo pump injection system; simulating gas injection and production under different operating conditions by setting true triaxial geostress conditions; comprehensively evaluating the quantitative assessment of the water edge by monitoring and collecting acoustic velocity, acoustic emission information, and wide-area electromagnetic signals during the gas injection and production process using pre-embedded sensors; and quantitatively evaluating the degree of water intrusion in the gas reservoir under long-term dynamic injection-production alternation using the above data. This invention can be used for the quantitative evaluation of the degree of water intrusion in gas reservoirs under long-term dynamic injection-production alternation, providing technical support for optimizing the injection-production system of depleted gas reservoirs.

The embodiment of the invention discloses a gas well reasonable production allocation method and device, electronic equipment, a storage medium and a computer program product. The method comprises the steps that target reservoir physical property data of a gas well to be subjected to production allocation located in a target block and a target production allocation chart of the target block are obtained, and the target production allocation chart represents the corresponding relation between at least one alternative combination and at least one alternative production allocation parameter; the at least one alternative combination is obtained by permutation and combination of at least one alternative water invasion risk level, at least one alternative reservoir space type and at least one alternative reservoir type; determining a target combination from the at least one alternative combination according to the target reservoir physical property parameters; and according to the target combination and the target production allocation chart, determining a target production allocation parameter from the at least one alternative production allocation parameter, and according to the target production allocation parameter, determining a reasonable production allocation result of the gas well to be subjected to production allocation. According to the technical scheme, reasonable production allocation of the gas well can be rapidly and accurately achieved.

The invention relates to a high gamma oil layer identification method, and belongs to the technical field of oil and gas field exploration and development. The high-gamma oil layer identification method comprises the following steps of determining a high-gamma sandstone section of a typical well drilling stratum and a reservoir type of the high-gamma sandstone section based on typical well data in a research area; then determining an evaluation index for representing the oiliness of the high-gamma sandstone section based on the gas logging response characteristics of the high-gamma sandstone section; and finally, performing rendezvous analysis on the basis of the corresponding relationship between the evaluation indexes of the high-gamma sandstone section and the reservoir types, and constructing an identification standard of the high-gamma oil reservoir in the research area. Experimental results show that when the recognition method is adopted to recognize the high-gamma oil reservoir, the accuracy is high, and the problem that the oil reservoir of the high-gamma oil reservoir cannot be effectively and accurately recognized can be solved.

The present application relates to gas well reservoir identification method technical field, it is a kind of gas well reservoir accurate identification method and device for eliminating coal seam interference, including using while drilling gamma curve, resistivity curve and lithology logging coal content ratio, confirm the existence of coal seam;Dynamic influence factor is calculated;Based on gas logging data correction formula, obtain the gas logging correction value of any depth point, based on resistivity correction formula, obtain correction resistivity;Combining gas logging correction value, correction resistivity, gas logging humidity ratio and acoustic time difference, distinguish reservoir type.The present application first corrects gas logging data and logging resistivity, eliminates the influence of coal seam on the gas logging data and the resistivity data, effectively removes the abnormal interference of coal seam on gas logging data and logging data, then combines the gas logging correction value, correction resistivity obtained after correction, gas logging humidity ratio and acoustic time difference, comprehensively determines whether the target layer is gas layer, and the present application improves the precision and efficiency of gas layer identification.

The invention belongs to the technical field of oil and gas exploitation methods, and particularly relates to a production allocation method for a gas well of a condensate gas reservoir type gas storage. The production allocation method for the gas well of the condensate gas reservoir type gas storage comprises the following steps that the radius range Rb of condensate oil separated out by well periphery reservoir chromatography of a single well under different production allocation gas rates Q is determined; determining a relational expression of reservoir pressure p and Q of the condensate gas reservoir type gas storage single well in the Rb range; calculating the total amount Qo of condensate oil separated by reservoir chromatography around the single well; determining a relational expression between the gas condensate production quantity Qo'and Q of the single well; according to the method, the gas preparation and production rate Qe is obtained through the fact that the Qo is equal to the Qo ', the separated condensate oil is completely displaced out of the stratum by the high-speed gas flow, the influence of the condensate oil is avoided, and therefore the purposes that the gas preparation and production rate is increased, and the peak regulation capacity of the gas storage is improved are achieved.

This invention discloses a method for exploiting shallow adsorbed shale gas, comprising the following steps: S101, based on core and well logging data, determining the shale gas occurrence characteristics, reservoir type, and main exploitation targets; S102, based on isothermal adsorption-desorption experiments, determining the adsorption-desorption law of the adsorbed gas and the sensitive desorption pressure P. 敏感 Based on the production characteristics, S103 selected the adsorption pneumatic drainage process to achieve large-scale production of shallow adsorbed shale gas.

The embodiment of the present application discloses a kind of prediction reserve upgrade evaluation method and device based on exploratory well test oil production prediction.Therein, the prediction reserve upgrade evaluation method based on exploratory well test oil production prediction includes: determining the reservoir type in the block to be evaluated prediction reserve based on the obtained data;Collect the exploration data of the determined reservoir type;Based on the exploration data, establish the exploratory well test oil production prediction model corresponding to the reservoir type;Determine the plane distribution of parameters in the prediction model;Based on the plane distribution and prediction model, determine the upgrade prediction reserve range;Based on the upgrade prediction reserve range, obtain the reserve scale in the upgrade range.Using the exploratory well data of the same or similar reservoir type as the block to be evaluated prediction reserve, effectively solve the problem of lack of exploration data in the block to be evaluated reserve, achieve the purpose of quantitative prediction of exploratory well test oil production, avoid single reliance on geological analysis to evaluate the upgradability of prediction reserve.

The present application relates to the technical field of gas reservoir development and efficient operation of gas storage, and particularly relates to a multi-cycle injection-production storage capacity dynamic prediction method for water-invasion gas reservoir type gas storage. The method comprises: obtaining injection-production experimental data of each cycle based on multi-cycle injection-production experiments; determining the phase permeability hysteresis coefficient, stress sensitivity coefficient, water invasion coefficient and water recession coefficient corresponding to each cycle based on the injection-production experimental data of each cycle; constructing a water invasion-seepage-pressure dynamic coupling model based on the phase permeability hysteresis coefficient, stress sensitivity coefficient, water invasion coefficient and water recession coefficient corresponding to each cycle; and predicting the storage capacity of the water-invasion gas reservoir type gas storage based on the water invasion-seepage-pressure dynamic coupling model. The present application solves the problems of storage capacity prediction deviation, insufficient experimental reproducibility and missing coupling model caused by dynamic interference of water invasion, stress sensitivity effect and hysteresis effect under water invasion conditions.

The invention relates to an intelligent prediction method for CO2 miscible flooding leading edge migration of an unconventional reservoir. The method comprises the steps that a CO2 miscible flooding leading edge migration prediction data set considering the type of the unconventional reservoir is established; the method comprises the following steps: establishing a CO2 mass transport equation considering an injection-production relationship, stress sensitivity and a starting pressure gradient on the basis of source-sink unit characterization of the dynamic injection-production relationship; constructing a convection diffusion equation considering a CO2-rock adsorption effect; constructing a CO2 miscible flooding front migration prediction model, and defining a CO2 miscible flooding front based on the prediction model; and introducing a pelican optimization algorithm to carry out fitting optimization on the permeability, the starting pressure gradient and the Langmuir adsorption constant, and dynamically optimizing the CO2 miscible flooding leading edge migration prediction model to realize intelligent prediction of CO2 miscible flooding leading edge migration. According to the method, the prediction of the leading edge migration in the process of improving the recovery efficiency by the CO2 miscible-phase flooding can be quantitatively and scientifically realized.

The invention belongs to the technical field of oil and gas field development engineering, particularly relates to a novel method and system for fracture and pore type reservoir numerical simulation history fitting, and aims at solving the problems that fracture and pore type reservoir numerical simulation history fitting is low in efficiency and poor in precision. The method comprises the following steps: constructing 3D geologic models of different oil reservoir types; initializing each static 3D model to obtain an oil reservoir dynamic model; performing simulation calculation on the oil reservoir dynamic model to obtain a relation equation of water content and recovery percentage of different pore medium reservoirs; constructing a relation chart of the water content and the recovery percentage of the reservoirs with different pore structures; the method comprises the following steps: acquiring relational data of water content and recovery percentage in a production process of an actual production well, matching the relational data with a chart, calculating a decision coefficient of a regression fitting equation of a matched crack-pore structure type, determining the crack-pore structure type of an area where the actual production well is located, and further adjusting historical fitting parameters to realize production historical fitting. According to the method, the efficiency and precision of reservoir numerical simulation history fitting are improved.

The application discloses a gas reservoir classification method and system, comprising: collecting characteristic data of all attributes of a combination of gas reservoirs to be classified, and dividing the characteristic data into numerical data and text data; determining a gas reservoir type matched with each text characteristic data according to a specified natural gas classification standard, and generating a one-hot encoding of each text characteristic data, further combining normalized numerical data to construct a similarity matrix used for calculating the similarity between gas reservoirs; obtaining a clustering result of the combination of the gas reservoirs to be classified by using the similarity matrix, and then determining a weight value representing the influence degree of each attribute on the clustering result and a best gas reservoir classification number; obtaining a classification result matched with the best gas reservoir classification number based on any attribute, and then evaluating the similarity between the gas reservoirs in each category in the current classification result by using the weight value to obtain a best classification result. The application realizes effective classification of the gas reservoirs under the condition of considering the overall characteristics of the gas reservoirs.

The invention discloses a determination method, a design method and a device for a transition area range of a gas reservoir type gas storage.The method comprises the steps that an injection-production well included in the periphery of a sweet spot injection-production area in a target gas reservoir type gas storage.The injection-production well is used as a unit, and the range of the transition area is determined on the basis of adjacent well interference of the injection-production well, the well type of the injection-production well and the horizontal section radiation direction of the injection-production well; constructing a gas flow model corresponding to the injection-production well by combining a gas seepage rule; based on the gas flow models corresponding to the injection-production wells, determining formation pressure distribution of all the injection-production wells included in the periphery of the sweet spot injection-production area at each sampling moment; and determining the transition area range of the gas reservoir type gas storage based on the formation pressure distribution of all the injection and production wells at each sampling moment. According to the method, the transition area range of the target gas reservoir type gas storage can be reasonably delimited according to the transition area ranges of all the injection and production wells on the periphery of the sweet spot injection and production area, the method is crucial to collaborative storage building and gas reservoir production, and a theoretical basis is provided for working system parameter design during gas storage operation.

The invention relates to the technical field of oil reservoir fracturing transformation, in particular to an oil well post-fracturing energy and yield increasing method which comprises the steps that the length and form of an artificial fracture of a reservoir, the closing pressure of the artificial fracture and the type of an oil reservoir during working area fracturing are obtained; selecting a well layer of which the yield decline type in the work area is a reservoir energy insufficiency type as a target well layer; determining an energizing liquid system according to the oil reservoir type; according to the length and the form of the artificial fracture of the reservoir, the liquid use scale is determined; according to the closing pressure, the construction displacement is determined; according to the energizing liquid system, the liquid using scale and the construction displacement, energizing liquid is injected into the target well layer, and in the injection process, the pump injection construction procedure is adjusted according to the remaining oil distribution condition; and after injection is completed, the soaking time is determined, and energy increasing after lamination of the target well is completed. A post-fracturing energy increasing process scheme is provided for a single well and a well group, effective maintenance of artificial cracks after target lamination is achieved, and the validity period of fracturing measures is prolonged.