China University of Petroleum

Jiyuan Zhang

Xianmin Zhang

Sen Wang

Qihong Feng

Yong Qin

Kun Wang

Wendong Wang

Xian Shi

Xiang Wang

Kuankuan Wu

Huajun Du

Zheng Wu

Yichun Wang

Yijing Du

Shunming Li

The present disclosure relates to a method for determining oil and gas relative permeabilities of a reservoir. The method includes: drilling a cylindrical core from a to-be-tested reservoir; injecting an oil and gas mixture into the cylindrical core through the piston container at a set flow rate by using the relative permeability testing device, and reducing pressures at a control end of the back pressure valve in sequence to obtain experimental values acquired under each pressure at the control end of the back pressure valve; equivalently simulating developing performance of a producing well of the to-be-tested reservoir using a one-dimensional numerical simulation grid model based on current oil and gas phase relative permeability curves, so as to obtain simulation values at different times; constructing an objective function according to the experimental and simulation values; determining whether a value of the objective function reaches a preset target value.

Method for determining oil and gas relative permeabilities of reservoir

The present disclosure relates to a method and system for predicting a time-varying principle of waterflooding oil reservoir formation parameters. Firstly, a Tspectrum-pore size relation model is built according to a measured pore size distribution curve and a measured Tspectrum. A Tspectrum of a rock sample at different water injection amounts during a waterflooding physical simulation experiment is acquired. The acquired Tspectrum at different water injection amounts is then converted into a pore size distribution at different water injection amounts, and a pore network model at different water injection amounts is built with the pore size distribution. Oil-water two-phase flow simulation is performed, and a corresponding oil-water two-phase relative permeability curve of the rock sample at different pore volume (PV) multiples is obtained eventually. The oil-water two-phase relative permeability curve is the formation parameters in the waterflooding oil reservoir.

Method and system for predicting time-varying principle of waterflooding oil reservoir formation parameters

The present disclosure relates to the technical field of oil-gas field development, and discloses a shale oil fracturing synchronous energizing simulation experimental device and method. The shale oil fracturing synchronous energizing simulation experimental device comprises a liquid supply system, a confining pressure loading system, a fracturing system, an energizing system and a recovery system, wherein the liquid supply system is used for storing fluid and can inject the fluid into the fracturing system; the fracturing system can bear a test piece, receive the fluid injected by the liquid supply system and serve as seepage space of the fluid; the confining pressure loading system is used for providing simulated confining pressure for the test piece; the energizing system is used for simulating an energizing effect on a test piece after fracturing liquid is injected; and the recovery system is used for collecting discharged liquid and separating and metering the discharged liquid.

Shale oil fracturing synchronous energizing simulation experimental device and method

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Qingdao, China

Jiyuan Zhang