5 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.

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 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.