9 results about "Pressure derivative" patented technology

Systems and processes for assessing connectivity between subterranean injector and producer wells. One process includes assessing pressure analytics before, during or after injection of stimulation fluid into a well. Pressure communication analytics includes analysis of pressure inflection at selected downhole locations and measuring one or more of: time to a first pressure inflection of a test fluid at the selected downhole locations; volume of test fluid pumped during time to first pressure inflection at the selected downhole locations; differential of pressure at the selected downhole locations from moment of the first pressure inflection to end of injection of test fluid in a well; pressure derivative at the selected downhole locations during entire time of injection of test fluid into the well; and pressure response at selected downhole locations at and post shut-in of injection of the test fluid, and composing a connectivity matrix which classifies observed pressure.

The application discloses a fault included angle angle value determination method, device, equipment, medium and product. The method comprises the following steps: obtaining wellhead production data and bottom hole flowing pressure data of a first oil well; normalizing the bottom hole flowing pressure data according to the wellhead production data to obtain normalized pressure data; calculating a pressure derivative curve corresponding to a pressure curve of the normalized pressure data; performing dimensionless processing on the pressure derivative curve according to characteristic parameters of an oil reservoir to obtain a dimensionless pressure derivative curve; and calculating a first fault included angle angle value of a fault area based on the dimensionless pressure derivative curve according to an unsteady seepage theory. The technical scheme of the application solves the problem that a well needs to be shut down for production to calculate a fault included angle, can convert variable production in historical data into fixed production, normalizes actual pressure of the oil well, and then calculates the fault included angle according to the normalized data, so that the well does not need to be shut down for production, the calculation accuracy is ensured, and oil well production loss is avoided.

This application discloses a method, system, device, and readable storage medium for determining reservoir permeability. The method comprises: obtaining formation pressure data from gas reservoir well tests at different time points; determining a logarithmic pressure curve and a logarithmic pressure derivative curve based on the formation pressure data; determining an intersection point between the logarithmic pressure curve and the logarithmic pressure derivative curve; and calculating the reservoir permeability of the gas reservoir well test based on the ordinate value of the intersection point. This method reduces the safety risks and testing costs of long-term testing and allows for simple and accurate calculation of reservoir permeability.

The present invention discloses a method for analyzing oil and gas well tests based on production data, comprising the following steps: establishing a normalized pressure equation according to a variable production convolution formula; acquiring long-term production data on site; performing rapid deconvolution calculation on the long-term production data based on the normalized pressure equation to obtain a pressure response function and its logarithmic time derivative, and preliminarily identifying characteristic flow segments based on the pressure response function and its logarithmic time derivative; establishing an accurate identification model for the characteristic flow segments based on the normalized pressure equation, accurately identifying the characteristic flow segments of the long-term production data based on the accurate identification model, and then performing parameter inversion using the characteristic flow segments to obtain formation parameters or dynamic reserves; and realizing rapid convolution inversion of pressure and pressure derivatives based on the production data based on the equation, thereby unifying traditional PTA and RTA methods to form a new method for analyzing production data well tests.

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 hydraulic power tool includes a trigger, a motor, a pump, a hydraulic circuit, a fluid reservoir, a pressure sensor, and a controller. When the trigger is depressed, the controller initiates motor operation, causing the pump to move hydraulic fluid through the circuit. The controller monitors pressure via the sensor, calculates a pressure derivative representative of a rate at which the pressure varies over time, and increments a buffer counter when the pressure derivative is zero or near zero. When the pressure derivative remains zero or near zero for a predetermined period of time, which indicates completion of a work operation, the controller automatically releases hydraulic fluid from the circuit back to the reservoir.

The present application belongs to the technical field of oil and gas field development, and particularly relates to a shale oil horizontal well support fracture width evaluation method. The evaluation method comprises the following steps: obtaining formation parameters, filling into Saphir to determine a diagnostic analysis model; importing pressure data and flow data into the diagnostic analysis model to obtain a pressure section history, a flow section history and a differential pressure-pressure derivative double logarithmic scatter plot; performing history matching on the differential pressure-pressure derivative double logarithmic scatter plot to obtain a differential pressure-pressure derivative double logarithmic curve, determine a variable wellbore storage pressure drop and a total pressure drop, and calculate a required fracture volume according to a main fracture half length, a fracture height and a variable wellbore storage time to calculate a fracture width. The evaluation method can effectively utilize field measured data, and the predicted fracture width has high accuracy.

The present disclosure provides a fault sealing evaluation method, device, and apparatus, relating to oil and gas exploration technology, comprising: obtaining basic data of a test well; obtaining pressure recovery data; determining a pressure derivative double logarithmic curve based on the basic data and the pressure recovery data; determining whether the shape of the pressure derivative double logarithmic curve presents a horizontal feature or a concave feature based on a preset template curve; if the pressure derivative double logarithmic curve presents a horizontal feature, the fault is determined to be sealed; if the pressure derivative double logarithmic curve presents a concave feature, the fault is determined to have flow conductivity. The pressure derivative double logarithmic curve can be constructed using the basic data and pressure recovery data obtained from the test well; then, by comparing the shape of the pressure derivative double logarithmic curve with the preset template curve, an evaluation of the fault sealing is obtained when the test well is located at a special position along the extension line of the fault.

The present application belongs to the technical field of oil and gas field development, and discloses a well pattern density calculation method and a well pattern density calculation device. The well pattern density calculation method comprises the following steps: S1, collecting basic parameters of a target oil reservoir; S2, drawing a pressure derivative curve in an open well stage or a closed well stage; S3, determining a time period Tp in which a radial flow section appears in the pressure derivative curve; S4, in the time period Tp, drawing a production well pressure drawdown funnel profile; S5, taking a preset pressure P as a measurement standard, and determining a distance from a well r in the production well pressure drawdown funnel profile; and S6, according to a ratio of injection wells to production wells of the target oil reservoir and the distance from the well r, calculating a total wellhead number of the target oil reservoir, and finally determining a well pattern density of the target oil reservoir. The well pattern density calculation method is simple, scientific and efficient, does not need to build a geological model and an oil reservoir model, and is free from the limitation of a conventional oil reservoir numerical simulation method, and has good practicability.