High-temperature and high-pressure shale reservoir imbibition evaluation device

Abstract

High temperature and high pressure shale reservoir imbibition evaluation device. The invention relates to the technical field of oil production evaluation in tight oil fields. There is a compression sleeve at the bottom of the pressure tank, a core is installed in the compression sleeve, a fracturing pipe is inserted into the countersunk hole of the core above the core, the fracturing pipe extends upward through the compression sleeve and is sealed with the compression sleeve, and the fracturing pipe passes through the pressure The flange cover of the tank is sealed with the flange cover. The invention has the following beneficial effects: by setting the compression sleeve to separate the core from the outside, the oil reservoir inside the core does not leak and seep out, the external pressure and temperature can act on the core, and the core can be kept under pressure by the pressure balancer Balanced, the oil and water distribution in the voids of tight oil reservoir cores will not change, simulating the process of fracturing fluid injection into the formation, soaking wells and imbibition displacement oil production, the fracturing fluid composition will be optimized, the time of soaking wells will be determined, and the amount of imbibition will be determined. The mechanism research has an important impact and provides effective experimental equipment for core imbibition experiments under high temperature and high pressure environment.

Description

Technical field:

[0001] The invention relates to the technical field of tight oil field oil recovery evaluation, in particular to a high-temperature and high-pressure shale oil reservoir imbibition evaluation device. Background technique:

[0002] Tight oil resources are extremely abundant at home and abroad. Due to the extremely low matrix permeability of tight oil reservoirs, the current mainstream development method at home and abroad relying on the energy depletion of natural formations can only use crude oil in the vicinity of fractures communicated by artificial fracture networks. The ultimate recovery of the reservoir can only reach 3-10% at most, and the use of surfactants to change the wettability of the reservoir to enhance the recovery has long been used in the development of conventional multi-fractured carbonate reservoirs , in order to promote the imbibition of the matrix by changing the wettability of the reservoir in the process of water flooding, so that the...

Images