6 results about "Pore pressure gradient" patented technology

The invention relates to the technical field of hydraulic engineering safety monitoring, and discloses an urban dike safety assessment method and system based on digital twinning. The method comprises the following steps: firstly, collecting pressure pulsation data of a dike deep drainage pipe network, a dike structure dynamic response data set and pore water pressure monitoring data; inverting an equivalent dynamic load through pressure pulsation data, and analyzing a seepage path in the dike by combining pore water pressure monitoring data; non-stable seepage analysis is completed based on the seepage path and the pore pressure data, and dynamic distribution of a pore pressure field is obtained; a dynamic-seepage abnormal coupling area is positioned through dynamic response and pore pressure field residual analysis, and the instability probability is quantified through pore pressure gradient divergence and slope displacement acceleration rate joint probability analysis; and finally, by means of a VR system integrated with a physical engine, visually demonstrating instability probability distribution and generating a dike risk evolution three-dimensional scene. The problem that existing dike safety assessment depends on single-dimension monitoring and is difficult to match with load dynamic changes, so that accuracy is insufficient is solved.

The invention relates to a method and device for judging whether an artificial CO2 gas cap is formed or not for an oil reservoir with a stratigraphic dip angle, and is applied to the oil reservoir with the stratigraphic dip angle. The method comprises the following steps that the CO2-crude oil capillary force gradient, the CO2 gas phase pore pressure gradient, the CO2 gas buoyancy force gradient and gravity gradient difference data of a target oil reservoir in the stratum direction of the CO2 injection well construction position are obtained; calculating a dimensionless numerical value formed by the artificial gas cap of the target oil reservoir based on a pre-constructed mechanical discrimination model for the dimensionless number of the artificial gas cap; and judging whether the dimensionless numerical value is greater than a first threshold value or not, if so, determining that the target oil reservoir artificial gas cap is formed, and if not, determining that the target oil reservoir artificial gas cap is not formed. The method can solve the problem that mechanical action mechanisms and conditions formed by the artificial gas cap of the oil reservoir with the dip angle are incomplete, imperfect and indefinite, and can conveniently judge whether the artificial gas cap can be formed by gas injection of the oil reservoir with the dip angle.

The invention provides a thermal desorption mass and heat transfer simulation method and system based on computer simulation, and relates to the technical field of computer simulation, and the method comprises the steps: obtaining a constructed geometric model of a polluted soil pile, and obtaining multiple groups of pore pressure gradients of different depths in the polluted soil pile at different moments and gas Darcy flow velocities of corresponding positions; carrying out regression analysis on the multiple groups of pore pressure gradients and the gas Darcy flow velocity through support vector regression, and calculating a permeability tensor; according to the permeability tensor of each grid unit, correcting a Darcy resistance item in the momentum conservation equation, and generating a gas seepage equation of each grid unit; carrying out simultaneous operation on the gas seepage equations of all the grid units to obtain a gas flow velocity field; and respectively substituting the velocity vector as a convection term parameter into a preset heat transfer equation and a pollutant transport equation to obtain a thermal desorption mass transfer and heat transfer simulation result, thereby realizing accurate simulation of dynamic permeability change caused by a gas slippage effect under high vacuum extraction.

A method for monitoring a risk to a stability of a wellbore in a subsurface formation includes receiving first input data 2024 / 243558 representing the wellbore or the subsurface formation. The method also includes extracting parameter-value pairs from the first input data. The method also includes determining an expected pore pressure gradient based upon the parameter-value pairs. The method also includes determining an expected fracture gradient based upon the parameter-value pairs. The method also includes determining a mud weight uncertainty profile for the wellbore based upon the expected pore pressure gradient and the expected fracture gradient.

Disclosed are methods, systems, and computer-readable medium to perform operations for calculating pore pressure in a reservoir, the operations including: receiving input data including: (i) a rock density in the reservoir, (ii) seismic data measured in the reservoir, and (iii) pore pressure measurement data from a Modular Formation Dynamic Tester (MDT); calculating, based on the rock density, an overburden pressure volume of the reservoir; generating, based on the overburden pressure volume, an overburden pressure volume of the reservoir; generating, based on the seismic data, an acoustic impedance volume of the reservoir; generating, based on the effective stress and overburden volumes, an estimated pore pressure volume of the reservoir; and calculating, based on the estimated pore pressure volume, a pore pressure gradient map indicative of the pore pressure in the reservoir.

The application provides an evaluation method for improving CO2 geological storage site screening and storage safety, which comprises the following steps: obtaining the regional plane structure diagram of the target layer, the formation pore pressure gradient and the formation temperature gradient through geological data analysis, calculating the pore pressure plane diagram and the formation temperature plane diagram of different target layers, combining the formation fluid salinity diagram, and calculating the CO2 density plane diagram and the CO2 solubility plane diagram of different layers. On this basis, the CO2 geological storage capacity plane diagram and the CO2 geological storage solubility plane diagram can be calculated by combining the reservoir physical property plane diagram and the CO2 storage coefficient. Then, the CO2 reinjection formation pressure change diagram can be quickly calculated according to the CO2 density diagram combined with the reservoir physical property diagram. The regional CO2 geological storage site comprehensive sweet spot plane diagram can be obtained by using the element superposition method combined with the above calculated elements. The analysis method of the application ensures the rapidness, efficiency and quantification of CO2 site screening, and changes the limitations and subjectivity of the prior art.