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Oil reservoir development mode optimization method based on starting pressure under flow coefficient

A technology for flow coefficient and reservoir development, applied in the fields of fluid production, earthwork drilling, measurement, etc., can solve problems such as inability to meet, the influence of starting pressure gradient, etc., and achieve a wide range of applications.

Inactive Publication Date: 2020-12-04
PETROCHINA CO LTD
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  • Abstract
  • Description
  • Claims
  • Application Information

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Problems solved by technology

However, the threshold pressure gradient is affected by both reservoir physical properties and fluid properties, and the development of low-permeability reservoirs is not a single water injection development
Existing threshold pressure gradient test methods only consider reservoir factors and are only applicable to water injection development reservoirs, which cannot meet the requirements of reservoir threshold pressure gradient tests for gas flooding, chemical flooding and other enhanced oil recovery technologies to improve the development effect of low-permeability reservoirs

Method used

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  • Oil reservoir development mode optimization method based on starting pressure under flow coefficient
  • Oil reservoir development mode optimization method based on starting pressure under flow coefficient
  • Oil reservoir development mode optimization method based on starting pressure under flow coefficient

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Embodiment 1

[0039] The first embodiment of the present invention relates to a method for optimizing the reservoir development mode based on the starting pressure under the flow coefficient, including the following steps:

[0040] Step 1) obtain the flow coefficient λ under different injection media and different permeability rock cores;

[0041] Step 2) testing the seepage velocity under different pressure gradients, and determining the start-up pressure gradients of injecting different media into different permeability cores;

[0042] Step 3) Under the same reservoir core permeability, according to the flow coefficient λ obtained in step 1) and the threshold pressure gradient obtained in step 2), establish the flow coefficient-threshold pressure where the abscissa is the flow coefficient and the ordinate is the threshold pressure gradient gradient curve;

[0043] Step 4) Calculate the flow coefficient of the development mode corresponding to the injection medium according to the reservo...

Embodiment 2

[0046] On the basis of Embodiment 1, this embodiment provides a method for optimizing the reservoir development mode based on the starting pressure under the flow coefficient. The specific process of step 1) is as follows:

[0047] (1) select at least five rock cores whose air permeability K ranges are 0.01mD-0.1mD, 0.1mD-1mD, 1mD-10mD, and 10mD-50mD respectively;

[0048] (2) Test and determine the viscosity μ of different injection media at reservoir temperature and pressure;

[0049] (3) Calculate the flow coefficient according to the core air permeability K and injection medium viscosity μ The flow coefficient λ under different injection media and different permeability cores is obtained, where K is the air permeability of the core, mD; μ is the viscosity of the measured fluid, mPa·s; λ is the flow coefficient, mD / mPa·s.

[0050] Select low-permeability core wells in the same block, and on the basis of ensuring that the lithology and mineral components are similar (the li...

Embodiment 3

[0053] On the basis of Embodiment 1 or Embodiment 2, this embodiment provides a method for optimizing the reservoir development mode based on the starting pressure under the flow coefficient, and the specific process of step 2) is as follows:

[0054] (1) After the rock core is dried, put it into a physical simulation device to evacuate;

[0055] (2) Heating to the temperature of the test reservoir, testing the formation pressure of the reservoir with end back pressure, and injecting an injection medium corresponding to a development mode into the core;

[0056] (3) Inject the injection medium in constant pressure mode, the initial injection pressure is set between 105% and 110% of the end back pressure, and the outlet flow rate is measured at the same interval;

[0057] (4) When the outlet flow rate is stable, change the injection pressure, measure the outlet flow rate at the same time interval until the outlet flow rate is stable, and obtain the seepage velocity under differ...

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Abstract

The invention provides an oil reservoir development mode optimization method based on starting pressure under a flow coefficient. The method comprises the steps of calculating the flow coefficient, testing starting pressure gradients of different fluids injected into rock cores with different permeability rates, establishing a flow coefficient-starting pressure gradient curve, and selecting reasonable development modes for different types of oil reservoirs according to test results. According to the method, the physical properties of a reservoir and the properties of the fluids are consideredat the same time, and the application range is wider (including various development methods such as water flooding, gas flooding and chemical flooding). The method can be used for evaluating the starting pressure gradients of different flow coefficients under the conditions of different low-permeability reservoir rock cores and different types of injected fluids. Meanwhile, the method is not onlysuitable for sandstone oil reservoirs, but also suitable for lithologic oil reservoirs such as low-permeability carbonate rock, conglomerate and shale, the application range is wide, and a quantitative basis is provided for optimization of different types of oil reservoir development modes, selection of the technical direction of improving the recovery efficiency and judgment of the permeability limit of the low-permeability oil reservoirs suitable for different injected fluids.

Description

technical field [0001] The invention belongs to the technical field of oil and gas field development, and in particular relates to a method for optimizing an oil reservoir development mode based on the starting pressure under flow coefficient. Background technique [0002] The main characteristics of low-permeability reservoirs are that the pore radius of fluid flow is small, the flow resistance is large, and the seepage law deviates from the classic Darcy linear flow, which belongs to nonlinear seepage. The nonlinear seepage characteristics are usually characterized by threshold pressure gradient. Threshold pressure gradient is one of the important parameters in the development of low permeability reservoirs, especially for the design of reservoir development well pattern and well spacing. [0003] At present, the threshold pressure gradient of low-permeability reservoirs is mainly obtained through indoor physical experiment simulation methods, testing the threshold pressur...

Claims

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Application Information

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IPC IPC(8): E21B43/16E21B49/00E21B47/00
CPCE21B43/16E21B49/00E21B47/00
Inventor 郑自刚王永宏张康熊维亮雷欣慧余光明张庆洲杨承伟袁颖婕曾山李姝蔓范伟
Owner PETROCHINA CO LTD
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