Rock carbonate oil reservoir flow channel adjustment construction process

Abstract

The invention discloses a rock carbonate oil reservoir flow channel adjustment construction process, and belongs to the technical field of rock carbonate oil reservoir flow channel adjustment. The process comprises a flow regulating slug injection step and a rear slug injection step, the flow regulating slug injection step refers to injection of a flow channel adjusting agent in a construction target well in a segmented mode, one flow regulating slug is injected every time the flow channel adjusting agent is injected, and the rear slug injection step refers to injection of oil field water or a polymer solution after each flow regulating slug; one post-slug is formed by injecting the oil field water or the polymer solution once; the slug amount of each flow adjusting slug is equal to the sum of the dosage volume of the flow channel adjusting agent and the dosage volume of the carrying liquid; and the using volume of the oil field water or the polymer solution of each rear slug is 1-3 times of the volume of the oil pipe. The process has been popularized and implemented for 25 well times since 2016, the accumulative oil increase is greater than 480,000 tons, and the water-driven use degree of the Tahe carbonate reservoir is improved by three percent points.

Description

technical field [0001] The invention belongs to the technical field of flow path adjustment of carbonate rock salt reservoirs, and relates to a construction process method for flow path adjustment of carbonate rock salt oil reservoirs. Background technique [0002] The fractured-vuggy carbonate reservoir in Tahe Oilfield is formed on a large paleo-uplift through multi-stage tectonic karstification, weathering crust karst controlled by paleogeomorphology, underground river karst controlled by paleohydraulic system, and fault-controlled karst controlled by faults. The main geological background is the reservoir with karst caves and fractures as the main storage space, the fractures are diversion channels, and the matrix basically has no storage and seepage capacity. Due to the large variation of the spatial scale of the fractured-vuggy body, the connection relationship is complicated. [0003] Since 2005, multi-well unit water injection and single-well water injection to repl...

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Problems solved by technology

[0010] The flow path adjustment requires the slow accumulation of particles to suppress the dominant water flow path. The technological processes and methods reported in the existing patents and literatures cannot meet the needs of the flow path adjustment construction of the water injection well group in the Tahe carbonate salt reservoir. The existing technology Most of the process is the traditional water plugging and profile control process, and the traditional water plugging and profile control process only injects liquid, and does not involve the injection of solid particles of the flow channel adjustment agent, nor does it involve problems related to particle concentration and particle-carrying liquid, and there is no problem of injection or failure , pump stop subsidence, near-well plugging and other problems. In addition, traditional water plugging and profile control techniques are mostly aimed at near-well operations, while flow channel adjustment processes are usually aimed at far-well operations. How to ensure that the solid particles of the flow channel adjustment agent are completely pushed into the formation , not to cause near wellbore plugging is a problem that needs to be considered, so it is necessary to study the process method suitable for flow channel adjustment construction of Tahe carbonate rock salt reservoir

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