19 results about "Tight gas" patented technology

A core permeability testing device and method are disclosed, belonging to the technical field of oil and gas field development. The testing device includes a core holder for holding the core to be tested; a constant temperature chamber for providing the testing environment temperature, which is equal to the temperature of the tight gas reservoir; the core holder and the core to be tested are placed inside the constant temperature chamber; a confining pressure loading pump for applying confining pressure to the core holder, the magnitude of which is equal to the pressure of the overlying strata of the tight gas reservoir; and a high-pressure gas cylinder for pressurizing a standard container, which is connected to the core holder. The standard container forms upstream and downstream pressures applied to the core holder according to the formation pressure of the tight gas reservoir. The core permeability under temperature, pressure, and saturation conditions is obtained by measuring and calculating. The testing device of this invention has a simple structure, and only pressure needs to be measured during the testing process, without the need to measure flow rate, which can effectively improve the evaluation effect of tight gas reservoir permeability.

The present application relates to the technical field of oil and gas field development, in particular to a kind of calculation method of reserve control degree of multi-layer superimposed tight gas reservoir.A kind of calculation method of reserve control degree of multi-layer superimposed tight gas reservoir, the reserve control degree of gas reservoir=(the control reserves of all gas wells-intersection control reserves-waste control reserves) / geological reserves of gas reservoir.The present application establishes a kind of calculation method of reserve control degree of multi-layer superimposed tight gas reservoir, considers the difference of different production layer control radius and control reserves, and has important guiding significance to the effective development of multi-layer superimposed gas reservoir.

The application discloses a method, device, equipment, medium and product for predicting fracture complexity of a tight gas reservoir section. The method comprises the following steps: determining a first fracture complexity index according to physical property parameters of cores of the tight gas reservoir section; determining an interlayer fracture mutual influence coefficient according to P-wave data of each layer in the tight gas reservoir section; and determining fracture complexity of the tight gas reservoir section according to the first fracture complexity index, the interlayer fracture mutual influence coefficient and the P-wave data of each layer in the tight gas reservoir section. The technical scheme can shorten the prediction period of the fracture complexity of the tight gas reservoir section, reduce the cost of predicting the fracture complexity of the tight gas reservoir section, and improve the accuracy of the predicted fracture complexity of the tight gas reservoir section.

This invention discloses a method and equipment for evaluating tight reservoir gas well parameters based on stress sensitivity, including: acquiring actual production data of the gas well; determining the reservoir stress sensitivity coefficient; obtaining a normalized production-mass balance pseudo-time curve, a normalized production integral-mass balance pseudo-time curve, and a normalized production integral derivative-mass balance pseudo-time curve considering stress sensitivity; fitting the above three curves to a typical curve chart for production instability analysis to determine the time shift, production shift, and position number; obtaining the dynamic reserves of the first gas well and the second gas well; using the average of the dynamic reserves of the first and second gas wells as the dynamic reserves of the gas well under the mutual constraint of the flow mass balance method and the chart fitting method; and calculating reservoir parameters and fracture parameters. This invention enables accurate evaluation of parameters such as dynamic reserves of gas wells in low-permeability tight gas reservoirs, and can conveniently, quickly, accurately, and effectively evaluate gas well parameters and reservoir parameters.

This application provides a method, system, and equipment for predicting the dynamic reserves of tight gas wells in sandstone lenses, relating to the field of oil and gas field development technology. This application calculates the average daily gas production in the first year of a typical gas well in a target well area using unobstructed flow data from multiple first reference gas wells. By acquiring production data from the reference gas wells and analyzing their decline patterns, a decline characteristic curve for the typical gas well is obtained. Based on the decline characteristic curve, the annual decline rate parameter is determined, and a EUR evaluation model is constructed by combining the average daily gas production in the first year and the annual decline rate. Finally, the cumulative gas production of the target gas well is calculated based on the EUR evaluation model, thereby determining its dynamic control reserves, improving the accuracy of production prediction and reserve estimation for tight gas wells in sandstone lenses.

The application is suitable for the technical field of oil and gas field stimulation and reconstruction, and provides a gas reservoir water lock releasing method based on adsorption-desorption dynamic balance regulation and control. The method first injects a low-concentration water lock releasing agent solution into a reservoir to form a non-saturated adsorption layer; then, a high-concentration water lock releasing agent is injected in a slug mode, and the surfactant component is redistributed and rearranged on the interface driven by the concentration gradient; by controlling the residence time, the interface molecules are partially desorbed and re-adsorbed to establish adsorption-desorption dynamic balance; combined with injection parameter window regulation and control, the periodic reconstruction of the interface structure and the release of water lock are realized. Through the synergistic mechanism of "staged injection-concentration gradient-residence regulation", the surfactant component presents a dynamic conversion behavior, effectively weakens the stability of the water film and promotes the release of bound water. The application does not depend on the structure of a specific chemical agent, has wide application range and strong interface regulation and control capability, and is suitable for the release of water lock in low-porosity and low-permeability and tight gas reservoirs.

The application discloses a kind of gas-water co-production tight gas reservoir fracturing horizontal well pseudo-steady state productivity calculation method, the application considers gas-water two-phase flow simultaneously by superposition principle, establishes the productivity equation of pseudo-steady state stage of multi-section fracturing horizontal well, analyzes the influence of factors such as fracture number, fracture half-length, production gas-water ratio, starting pressure gradient, slip effect, effective permeability and fracture conductivity on initial open flow capacity of gas well.The specific productivity equation construction steps are as follows: S1, establish single fracture single-phase gas productivity equation;S2, ignore the difference between fracturing cracks to establish single-phase gas well total productivity equation;S3, two-phase pseudo-pressure is introduced into gas well productivity equation to obtain gas-water two-phase fracturing horizontal well productivity equation;S4, slip factor, starting pressure gradient nonlinear factor two factors are introduced into two-phase fracturing horizontal well productivity equation.

The application discloses a kind of compact gas reservoir fracturing horizontal well classification method and system, the method includes collecting the productivity influence factor and corresponding historical characteristic parameter of each fracturing horizontal well in target well area during the production process in historical period, and historical production, and the correlation between productivity influence factor and production is analyzed, to screen and classify the factors suitable for process;Using the historical characteristic parameter and historical production corresponding to the screening factor to train the preset model, obtain the production prediction model, and then use the characteristic parameter corresponding to the screening factor of each fracturing horizontal well during the production process in current period, obtain the corresponding predicted production;The contribution characteristics of the screening factor of each fracturing horizontal well to the predicted production are obtained, and then combined with the predicted production, a plurality of clusters representing different fracturing horizontal well types are formed through cluster analysis, to obtain the corresponding classification result.The application realizes the reasonable classification of compact gas reservoir fracturing horizontal well.

The application relates to a wetting reversal agent and a preparation method and application thereof, and belongs to the technical field of unconventional oil and gas exploitation. Raw materials of the wetting reversal agent include strong hydrophobic modified nano silicon dioxide and a synergist; the strong hydrophobic modified nano silicon dioxide is obtained by modifying and treating nano silicon dioxide with heptadecafluorodecyltrimethoxysilane; and the synergist includes polydimethylsiloxane, glycerol trioleate and 2-ethylhexanol polyoxyethylene ether. According to the embodiment of the application, the excellent water-repellent performance provided by the strong hydrophobic modified nano silicon dioxide and the surface tension reduction effect brought by the synergist are synergized, a more effective water lock inhibition system is formed, and the system jointly acts on the key link of the water lock problem possibly occurring in the fracturing process of deep tight gas reservoirs, so that the water lock inhibition capacity of the wetting reversal agent is improved in all directions.

This invention belongs to the field of oil and gas reservoir development and discloses an integrated simulation method for water-lock damage in tight gas reservoirs involving fracturing and flowback. By acquiring scanning data from tight reservoir cores, a binary digital core model reflecting the true pore structure is constructed after preprocessing. A pore-scale two-phase flow numerical calculation model is established using the color gradient multiphase flow lattice Boltzmann method. Based on this model, the fracturing fluid invasion and flowback processes are simulated in an integrated manner, dynamically tracking the migration, distribution, and retention evolution of the water phase in the pore network. The water-lock permeability damage rate is quantitatively determined by calculating the gas phase permeability before and after fracturing fluid invasion. Furthermore, sensitivity analysis is conducted on key factors such as fracturing fluid viscosity, interfacial tension, and reservoir properties. This invention achieves continuous coupled characterization of the entire fracturing-flowback process, revealing the dynamic formation mechanism of water-lock damage at the microscopic level, and solving the problem of poor stability of existing pore-scale simulation methods in high-density gas-water systems.

The application discloses a method, equipment and storage medium for accurately obtaining productivity of a low-permeability tight gas well by non-well-closing testing, and specifically comprises the following steps: S1, collecting oil testing data when the gas well is opened; S2, collecting gas production of the gas well at a time t, production history data of the gas well from opening to the time t, wellhead casing pressure change data, well structure data of the gas well and fluid PVT data; S3, recording wellhead casing pressure change data of the gas well from opening to a time t+Delta t; S4, calculating bottom-hole flowing pressure of the gas well at the time t and the time t+Delta t; S5, adopting binomial productivity equations in a pressure square form, and combining binomial productivity equation groups corresponding to different production stages; S6, modifying the binomial productivity equation groups in the step S5, solving to obtain productivity equation coefficients of the gas well and formation static pressure, and calculating to obtain productivity of the gas well.

This invention provides a method, apparatus, equipment, and medium for production prediction based on time-varying reservoir parameters. The method includes the following steps: S1, establishing a variable decline exponential production decline model for tight gas reservoir wells; S2, collecting historical gas production data of tight gas reservoir wells, and confirming the second undetermined characteristic parameter β and establishing a first linear model based on linear fitting of lnq and t / (lnt)β, wherein the slope of the first linear model is -α and the intercept is lnq. i Value; and S3, confirming the theoretical initial output q based on the first linear model. i The invention uses a first undetermined characteristic parameter α to predict gas well production using the variable decline exponent production decline model. This invention better reflects the production decline law of tight gas wells, is simple to operate, and has higher prediction accuracy than traditional decline models with a constant decline exponent. It can be widely used for production decline prediction in tight gas reservoirs.

This invention relates to the fields of oil and gas reservoir development and digital oilfield technology, and provides an adaptive water-lock removal method based on interface behavior feedback control. The method includes: online monitoring of interfacial tension, contact angle, water cut, and pressure; calculation of interfacial response parameters and water-locking degree indices, inputting them into a decision model to generate a control strategy; injecting a water-lock removal agent according to the control strategy, adjusting the concentration, injection rate, and injection method; continuously collecting data during injection and feeding it back to the decision model for dynamic correction; repeating the above steps until the convergence criterion is met, at which point control stops. This invention, by constructing a collaborative mechanism of "online monitoring—interface characterization—intelligent decision-making—dynamic control," transforms the water-lock removal process from experience-driven to data-driven adaptive control. In low-porosity, low-permeability, and tight gas reservoirs, it can significantly reduce capillary resistance, improve gas phase permeability, and restore gas well productivity.

A method for optimizing a shut-in time of an intermittent well of a tight gas reservoir, and a device. The method comprises: acquiring casing pressure data after shut-in and shut-in durations corresponding to the casing pressure data; acquiring the change trend of the shut-in durations and determining a casing pressure recovery rate threshold on the basis of the casing pressure data, the change trend and a gas well pressure stabilization standard; performing a curve fitting operation on the casing pressure data and the shut-in durations to establish a pressure drop rate model; and obtaining an optimized shut-in duration on the basis of the pressure drop rate model, fitted curve parameters and the casing pressure recovery rate threshold. By collecting production data of a gas well in real time, the real-time production data of the gas well reflects the influence on gas well production when wellbore liquid loading and piping freeze blockage occur during an actual production process of an intermittent gas well of a tight gas reservoir, and has strong reliability, thereby improving the production efficiency of the intermittent gas well of the tight gas reservoir, and fully utilizing the production capacity of the intermittent gas well.

The present application relates to a kind of composite proppant and fracturing fluid system thereof, adopt secondary coating technology granulation forming.First coating is coated by high molecular polymer;Second coating is coated by water-soluble coating material with ecological environmental protection, low density, hydrolyzable, salt-resistant, acid-resistant and lubricating, which is coupled and coated on the surface of coated sand, and the proppant is produced by processes such as drying, forming and screening, which has the functions of self-suspension, self-friction reduction and self-hydrolysis.The proppant integrates proppant and main additives of fracturing fluid, and has the technical characteristics of high strength, low density, high suspension, low viscosity, high sand ratio, low friction, high yield and low damage.The composite proppant is suitable for hydraulic fracturing construction and reservoir reconstruction of medium-deep shale gas and tight gas, and has the advantages of functional integration, simple construction, clean water fracturing, cost reduction, full-slit sand placement, efficient yield increase, sufficient hydrolysis, damage reduction, liquid preparation diversity, strong adaptability, free-burning forming, energy saving and carbon reduction.

The application provides a reservoir fluid identification method, device, equipment and medium. It relates to the technical field of tight gas reservoir fluid identification. The method comprises the following steps: obtaining well logging data of a target work area; constructing a training sample set based on the well logging data, screening sensitive well logging parameters, and establishing a parameter combination space covering different missing situations; training a missing parameter self-adaptive compensation model for each missing situation; constructing a parameter self-adaptive fluid identification model based on complete samples and compensated samples; obtaining measured parameters of a well to be identified, calling a corresponding compensation model to complete the missing parameters, and then inputting the parameters into the identification model to obtain a fluid type identification result. The application can adapt to changes and missing of well logging parameters, avoid repeated modeling, and improve identification accuracy.

The application discloses a kind of method and related devices for determining low-permeability-dense gas reservoir gas well dynamic reserves, belong to gas field development technical field;The method first determines that gas well enters quasi-steady state time, and the gas well with production time greater than quasi-steady state time is screened out as to-be-evaluated gas well for subsequent dynamic reserve evaluation;Determine the deviation factor and gas viscosity variation curve of to-be-evaluated gas well;According to the deviation factor and gas viscosity variation curve, calculate the pseudo pressure of to-be-evaluated gas well;Calculate the superposition yield of to-be-evaluated gas well under different production time;According to the pseudo pressure of evaluation gas well and the slope of superposition yield under different production time, calculate the slope of superposition yield normalization pseudo pressure and production time curve;Further, the dynamic reserve of to-be-evaluated gas well is calculated.The application solves the problem that the application degree of existing method is limited, and the evaluation quality is poor, improves the dynamic evaluation index level of this kind of gas reservoir, and provides reliable opinion for further realizing gas field development technical countermeasure adjustment.

The present application belongs to the technical field of oil and gas reservoir development, and particularly relates to a gas-water two-phase productivity numerical simulation method, device, medium and product. The method comprises the following steps: constructing a physical model of tight gas reservoir sandstone based on rock physical parameters; constructing a physical parameter dynamic model suitable for the stage of injecting fracturing fluid according to a relative permeability hysteresis algorithm based on the physical model of the pore structure of the tight gas reservoir sandstone; obtaining a relative permeability hysteresis curve of the stage of injecting fracturing fluid and backflow based on the physical parameter dynamic model; and performing gas-water two-phase productivity numerical simulation based on the relative permeability hysteresis curve. The present application can accurately describe and predict the influence of gas phase hysteresis effect on productivity.