16 results about "Reservoir pressure" patented technology

The present application relates to a kind of fracturing fluid flowback period gas well productivity evaluation method, steps are as follows: obtaining gas component, and the relationship curve of pressure and gas density, gas viscosity is calculated to obtain;The ratio of water phase and gas phase relative permeability is calculated, and the relationship curve of pressure and gas phase relative permeability, water phase relative permeability is respectively interpolated to obtain;The relationship curve of pressure and pseudo pressure is obtained;Fracturing fluid flowback period water-gas ratio and bottom hole flowing pressure are calculated, and based on the relationship curve of pressure and pseudo pressure, pseudo pressure under gas reservoir pressure and bottom hole flowing pressure is respectively calculated by interpolation, and the total flow of gas and water is calculated, then the average of test point is calculated;Bottom hole flowing pressure and water-gas ratio are set, pseudo pressure under the set bottom hole flowing pressure is calculated, and combined with average, the open flow capacity of gas well is obtained.The present application establishes gas-water two-phase seepage under gas well productivity calculation mathematical model, realizes the accurate calculation of gas well productivity under gas-water two same production condition.

This invention relates to the field of collaborative well testing technology for coal reservoirs, specifically disclosing a constant flow rate-limited pressure collaborative control method and system for coal reservoir well testing. The method includes: collecting cluster-single-well dual-dimensional parameters; constructing a regional reservoir pressure field coupling model based on the dual-dimensional parameters, wherein the regional reservoir pressure field coupling model embeds fluid-structure interaction equations and a pulverized coal critical velocity model; configuring a cluster-single-well dual-level priority dynamic allocation rule based on the dual-dimensional parameters; and configuring a cluster-level multi-objective optimization algorithm with single-well flow deviation, single-well pressure, regional pressure field uniformity, and cluster pulverized coal blockage risk as constraint indicators. This invention successfully resolves the contradiction between rapid pressure relief and prevention of pulverized coal explosions, minimizing reservoir damage and wellbore blockage risks while ensuring well control safety, and significantly improving the success rate and data quality of coalbed methane well cluster testing operations.

This invention discloses a low-cost thermally activated pressure-controlled development method and system for improving the recovery rate of shallow gas in offshore areas. It relates to the field of shallow gas development technology. The method includes: deploying horizontal heating and water injection channels at the bottom, lower part, or near the outer boundary of the shallow gas reservoir; transporting and injecting high-temperature seawater from the sea surface or near the sea surface into the bottom or lower reservoir layer; employing a slow depressurization and pressure window control method in the production well to maintain the reservoir pressure within a range higher than the gas pore connectivity disruption pressure but lower than the caprock breakthrough pressure; installing a variable-diameter sand-control production cylinder in the open-hole production section of the production well; and transporting the developed natural gas to a seabed natural gas hydrate formation shed or container, utilizing the low-temperature, high-pressure environment of the seabed to form natural gas hydrates, thereby achieving low-cost storage and transportation. This invention achieves shallow gas reservoir heating, dissolved gas desolvation, gas-water displacement, pressure control and stable production, and efficient sand control with low energy consumption, thereby improving the recovery rate and economic efficiency of shallow gas development in offshore areas.

The present application relates to the technical field of petroleum geological exploration, and specifically discloses a method for exploring geological tight oil of a lower combination of Yanchang Formation in Ordos Basin, which screens effective formation water samples through double indexes, establishes a three-dimensional mineralization degree spatial distribution body and dynamically corrects water saturation, fuses oil saturation, seismic attributes and core mercury injection data to construct a multi-source feature matrix, applies differential correction to three types of low-resistance causes, namely, high bound water type, high mineralization type and micro-fracture conductive type, trains a sweet spot prediction model by using a random forest and XGBoost integrated learning framework, introduces a SHAP method to verify geological interpretability, generalizes the solidified model to the whole area to obtain a three-dimensional sweet spot probability body, introduces a source-reservoir pressure difference driving index to perform reservoir forming dynamics weighted correction, and grades favorable exploration target areas according to a probability threshold to output recommended well location coordinates, effectively solving problems such as low-resistance oil layer misjudgment, lack of interpretability in prediction, and lack of reservoir forming dynamic constraints in spatial evaluation.

A method of determining average reservoir pressure for a subterranean formation is provided. The method includes shutting in a well in the subterranean formation; measuring a plurality of buildup pressures during a period of time wherein the well is shut in via a downhole pressure gauge; performing an eigen expansion of the plurality of buildup pressures to generate a plurality of eigenvalues; determining an estimated average reservoir pressure based, at least in part, on the plurality of eigenvalues; and producing fluids from the well based, at least in part, on the estimated average reservoir pressure.

The application discloses a kind of ultra-low permeability reservoir pressure control profile control methods, comprising: obtaining oil well data, according to oil well data, calculate total liquid volume of profile control plug and each plug liquid volume;According to total liquid volume of profile control plug and each plug liquid volume, configure oil reservoir protection plug in pre-plug, main body plugging agent in main body plug and deblocking plug in post-plug;The prepared pre-plug, main body plug and post-plug are sequentially injected into formation, and after shut-in reaction, subsequent conventional injection and production operation is carried out.The present application can effectively protect the near-wellbore reservoir of ultra-low permeability reservoir by reasonable plug combination design, and provides an accurate calculation method for the main profile control plug, improving the pertinence and applicability of water plugging and profile control in ultra-low permeability reservoir.

This invention discloses a composite unblocking agent for shale gas reservoirs and its preparation method. The composite unblocking agent comprises the following raw materials in parts by weight: 5-15 parts oxidant, 0.1-1 parts corrosion inhibitor, 1-5 parts buffer, 1-5 parts co-solvent, 5-15 parts scale remover, 1-5 parts synergist, 1-5 parts dispersant, 0.1-1 parts regulator, 10-20 parts organic solvent, 0.1-0.5 parts gelling agent, and 50-70 parts water. This composite unblocking agent contains multiple unblocking components, can be used to unblock different types of plugs, and forms a synergistic effect, significantly improving the unblocking effect and rate while also increasing reservoir pressure and production. It is suitable for large-scale application in shale gas reservoir unblocking treatment.

This application discloses a method, apparatus, electronic equipment, and storage medium for draining fluid from a shale gas horizontal well, relating to the field of shale gas extraction technology. The method includes: obtaining the initial production rate of the target shale gas horizontal well; calculating the expected shale gas production rate under different preset draining rates based on the initial production rate, a preset production time, a first production loss coefficient, and a second production loss coefficient, wherein the first production loss coefficient reflects the degree of production reduction caused by reservoir pressure depletion, and the second production loss coefficient reflects the degree of production reduction caused by reservoir stress sensitivity; determining the target draining rate among the preset draining rates based on the expected shale gas production rate; and performing draining operations on the target shale gas horizontal well according to the target draining rate. This application, by introducing a production loss coefficient, accurately simulates the declining trend of gas well production, optimizes the draining rate, thereby improving gas well production efficiency, reducing human error, and effectively enhancing recovery rate and production.

The application discloses a device and method for simulating gas enrichment migration amount of matrix fractures in different depth reservoirs. The device comprises a constant pressure displacement system, a first sealed intermediate container, a second sealed intermediate container, a first gas collection system and a second gas collection system, a core holder, a first control valve, a second control valve and a third control valve, etc. The application provides an experimental device for establishing original gas amount of shale matrix and fracture system, which is used for simulating gas migration process in the fracture and matrix system under different pressures of different reservoir depths, obtaining variation law of reservoir matrix gas content and fracture system gas content with pressure coefficient, and determining gas relative migration amount of shale matrix and fracture system under different reservoir pressures, so as to provide a theoretical basis for shale sweet spot area optimization and development technology optimization.

FIELD: oil production.SUBSTANCE: invention relates to a method and system for oil production. The extracted product is fed into the oil collection manifold. Reservoir pressure is maintained using injection wells. Water is pumped into the ejector nozzle. After measuring the flow rates of production wells, the associated petroleum gas is separated from the produced water-oil-gas mixture and pumped out using an ejector with the possibility of implementing wave modes of operation of oil production wells. The water-gas mixture is dispersed and the pressure is increased, followed by pumping the water-gas mixture into one or several injection wells and further into the formation using a booster pump. Reagents are dosed. Associated petroleum gas is separated from the water-oil-gas mixture together with pumping of the products of oil producing wells into an oil collection manifold using a frequency-controlled booster pump. The pressure is reduced at the mouth of oil production wells and in the annular space of oil pumping production wells, increasing the flow rate of oil production wells and increasing the flow rate of gas fed to the ejector intake. Wave modes of operation of oil production wells are implemented by means of joint frequency regulation of booster, charge and submersible well pumps.EFFECT: increase in the efficiency of oil production. The method includes the operation of oil production wells and measuring their flow rates.6 cl, 3 dwg

The present application belongs to the field of petroleum industry, and particularly relates to a method and device for evaluating the storage capacity characteristics of a carbonate rock gas reservoir type gas storage, which comprises: obtaining reservoir characteristic data and to-be-evaluated storage capacity characteristics of a to-be-evaluated gas storage; obtaining an evaluation parameter from a set of storage capacity characteristic evaluation parameters according to the reservoir characteristic data and the to-be-evaluated storage capacity characteristics; the evaluation parameter comprises reservoir pressure corresponding to oil and gas reserves under different reservoir characteristic data, and fracture and hole characteristics corresponding to different reservoir characteristic data; and determining an evaluation result of the storage capacity characteristics of the gas storage according to the reservoir characteristic data and the evaluation parameter. The present application solves or partially solves the problem of how to assist in evaluating the storage capacity characteristics of a carbonate rock gas reservoir type gas storage.

This invention belongs to the field of oil and gas development, specifically relating to a method for characterizing reservoir water cut distribution. The method includes: establishing oil-water phase permeability curves based on experiments measuring the relative permeability of two-phase fluids in rocks; combining this with reservoir water saturation data to obtain oil phase relative permeability field data and water phase relative permeability field data; establishing fitting relationships between crude oil viscosity and reservoir pressure, and between crude oil volume coefficient and reservoir pressure, based on reservoir fluid property analysis experiments; combining this with reservoir pressure data to obtain oil phase viscosity field data and oil phase volume coefficient field data; establishing a water cut calculation formula; and establishing a reservoir numerical model based on the calculation formula to generate a water cut distribution map. The water cut distribution map generated using this method can characterize the water cut distribution at different stages of reservoir development, providing a more refined representation of reservoir water cut distribution and potential, and offering a more scientific basis for evaluating water drive development effectiveness and formulating reservoir adjustment plans.

Embodiments of the present application provide a gas reservoir water invasion simulation method and device, electronic equipment and storage medium. The method is based on the microscopic image of the casting section of the target gas reservoir, constructs a pore structure geometric model, and constructs a water body model on one side of the pore structure geometric model to form a pore-water coupling model. Then, under the conditions of the reservoir pressure and constant pressure difference corresponding to each development stage, the water invasion simulation is performed by using the pore-water coupling model to obtain the simulation results of each development stage. Then, based on the simulation results of each development stage, the water invasion characteristic parameters of the target gas reservoir are determined to predict the water invasion risk trend of the target gas reservoir at different development stages in the development process. The method accurately depicts the water invasion behavior characteristics at different development stages, and provides a reliable basis for the adjustment and optimization of the gas reservoir development plan.

The present application relates to the technical field of fracturing fluid additive, and is a tight sandstone pore permeability improvement agent system and a method for hole expansion and throat enlargement, the former comprising multistage acid, fluoroboric acid, iron ion stabilizer and water, and the following steps are performed: a required amount of multistage acid is uniformly mixed with the iron ion stabilizer to obtain A liquid; clean water is prepositioned, and is injected into a formation from a sand mixing vehicle to replace formation water in a perforation hole, clean the perforation throat, immediately inject the obtained A liquid into the perforation throat, then immediately inject fluoroboric acid into the reservoir, and finally immediately inject clean water as a spacer fluid; after the reservoir pressure drop is greater than or equal to 12 MPa, a preflush, a sand-carrying fluid, a displacement fluid are injected, and normal fracturing operations are carried out. The present application generates hydrofluoric acid by the reaction of multistage acid and fluorine salt to achieve the purpose of expanding and enlarging the tight pore throat, has significant corrosion inhibition and strong casing protection function, and simultaneously compounding the iron ion stabilizer as a protective agent to avoid injection damage to the reservoir.

The application discloses a kind of based on numerical simulation's pressure drive limit well spacing determination method, comprising: establishing low-permeability reservoir pressure drive well group geological model;Establishing pressure drive development double-hole double-permeability numerical simulation model;Determine the pressure drive limit well spacing judgment standard;Establish the pressure drive limit well spacing prediction factor set;Establish the pressure drive limit well spacing prediction sample program design table and pressure drive limit well spacing prediction sample library;Establish the pressure drive limit well spacing prediction model.The present application can provide support for the formulation of low-permeability oilfield pressure drive development plan and the compilation of high-quality plan, and has important significance for achieving good results in pressure drive development plan.

This application provides a reservoir pressure-driven enhanced oil recovery simulation system and method, relating to the field of petroleum development. The reservoir pressure-driven enhanced oil recovery simulation system includes a test formation that can simulate an actual oilfield. It utilizes pressure-driven technology to expand the pores of the reservoir containing the oil sample by pressurizing the test formation. Various pressure-driven fluids are injected into the test formation, and the recovery rate corresponding to each fluid is determined based on the mixture produced. By comparing the recovery rates of different pressure-driven fluids, the reservoir pressure-driven enhanced oil recovery simulation system can identify the most suitable pressure-driven fluid for the current test formation. When the oil sample is crude oil, this pressure-driven fluid can maximize the extraction of crude oil from the oilfield, thereby improving the oil recovery rate.