4D quantitative and intelligent diagnosis method and system for spatio-temporal evolution of oil-gas reservoir damage types and extent

Patent metadata

Field	Value
Publication number	US-11686190-B2
Application number	US-202217864224-A
Country	US
Kind code	B2
Filing date	Jul 13, 2022
Priority date	Aug 26, 2020
Publication date	Jun 27, 2023
Grant date	Jun 27, 2023

Abstract

A 4D quantitative and intelligent diagnosis method for spatio-temporal evolution of oil-gas reservoir damage types and extent includes: determining a characteristic parameter characterizing reservoir damage by each of a plurality of factors based on a spatio-temporal evolution simulation equation of reservoir damage by each of the plurality of factors; and determining an effective characteristic parameter characterizing the damage extent of the reservoir based on the characteristic parameter characterizing reservoir damage by each of the plurality of factors. The method quantitatively simulate the characteristic parameters of reservoir damage caused by the various factors and a total characteristic parameter of the reservoir damage.

First claim

The invention claimed is:

1. A method for determining a damage extent of a reservoir, comprising:
drilling a well to be diagnosed to the reservoir;
applying a pressure to drive a fluid containing flowing particles to continuously intrude from a wellbore of the well to be diagnosed into the reservoir;
determining a characteristic parameter characterizing reservoir damage by each of a plurality of factors based on a spatio-temporal evolution simulation equation of reservoir damage by each of the plurality of factors, wherein the reservoir is located in a preset region of the well to be diagnosed; and
determining an effective characteristic parameter characterizing the damage extent of the reservoir based on the characteristic parameter characterizing reservoir damage by each of the plurality of factors,
wherein the well to be diagnosed is a water injection well, a polymer injection well or an oil production well, the plurality of factors comprise extraneous solid-phase particles, the method further comprising:
when the well to be diagnosed is in a drilling stage, determining a spatio-temporal evolution simulation equation of reservoir damage by the extraneous solid-phase particles by the following modeling process:
determining a velocity of the fluid containing flowing particles in the reservoir;
establishing a mass balance equation between the fluid and deposited particles on rock in the reservoir, based on a convection parameter and a diffusion parameter of the fluid;
establishing a connection condition equation between a volume concentration of the deposited particles and a volume concentration of the fluid, based on the convection parameter and the diffusion parameter of the fluid; and
determining the spatio-temporal evolution simulation equation of reservoir damage by the particles according to a relationship between a mass fraction of the flowing particles and a volume concentration of the flowing particles, the velocity of the fluid, the mass balance equation and the connection condition equation, wherein the spatio-temporal evolution simulation equation is used to simulate a four-dimensional spatio-temporal evolution process of characteristics of reservoir damage caused by the extraneous solid-phase particles.

2. The method for determining the damage extent of the reservoir according to claim 1 , wherein when the well to be diagnosed is in the drilling stage, the plurality of factors further comprise at least one of: clay swelling, migration of fine particle within the reservoir, inorganic precipitation, and water lock effect;
wherein when the well to be diagnosed is an oil production well and is in an oil production stage, the plurality of factors further comprise at least two of: migration of fine particle within the reservoir, sand production, emulsification, Jamin effect, stress sensitivity, wettability reversal, and organic scale;
wherein when the well to be diagnosed is a water injection well and is in a water injection stage, the plurality of factors further comprise at least two of: clay swelling, bacteria, water lock effect, extraneous solid-phase particles, fine particle migration, and inorganic precipitation; or
wherein when the well to be diagnosed is a polymer injection well and is in a polymer injection stage, the plurality of factors further comprise at least two of: polymer, clay swelling, extraneous solid-phase particles, fine particle migration, and inorganic precipitation.

3. The method for determining the damage extent of the reservoir according to claim 2 , further comprising: determining a spatio-temporal evolution simulation equation of reservoir damage by the migration of fine particle within the reservoir by the following modeling process:
determining a velocity of a fluid in the reservoir;
establishing a mass balance equation between the fluid and deposited fine particles on rock in the reservoir, based on a convection parameter and a diffusion parameter of the fluid and a mass change rate of migrating fine particles in the fluid, wherein there is a correlation between the mass change rate of the migrating fine particles and the velocity of the fluid;
establishing a connection condition equation between a volume concentration of the deposited fine particles and a volume concentration of the fluid, based on the convection parameter and the diffusion parameter of the fluid; and
determining the spatio-temporal evolution simulation equation of reservoir damage by the migrating fine particles within the reservoir according to a relationship between a mass fraction of the migrating fine particles and a volume concentration of the migrating fine particles, the velocity of the fluid, the mass balance equation and the connection condition equation, wherein the spatio-temporal evolution simulation equation is used to simulate a four-dimensional spatio-temporal evolution process of characteristics of reservoir damage caused by the fine particles.

4. The method for determining the damage extent of the reservoir according to claim 2 , further comprising: determining a spatio-temporal evolution simulation equation of reservoir damage by the clay swelling by the following modeling process:
determining a Darcy apparent velocity of a fluid in the reservoir;
establishing a mass balance equation for water molecules in the fluid according to the Darcy apparent velocity of the fluid and a diffusion coefficient of the water molecules in the fluid;
establishing a diffusion equation for diffusion of the water molecules in the fluid to the interior of rock in the reservoir according to Fick's law of diffusion; and
determining the spatio-temporal evolution simulation equation of reservoir damage by the clay swelling according to the diffusion equation and the mass balance equation, wherein the spatio-temporal evolution simulation equation is used to simulate a four-dimensional spatio-temporal evolution process of characteristics of reservoir damage caused by the clay swelling, and the clay is a component of the rock.

5. The method for determining the damage extent of the reservoir according to claim 2 , further comprising: determining a spatio-temporal evolution simulation equation of reservoir damage by the water lock effect by the following modeling process:
determining a Darcy apparent velocity of a fluid in the reservoir;
establishing an aqueous phase motion equation of the reservoir according to the Darcy apparent velocity of the fluid and a diffusion coefficient of water molecules in the fluid;
establishing a permeability distribution equation of the reservoir according to pore size distribution characteristics of pores of the reservoir and a preset permeability model of the reservoir; and
determining the spatio-temporal evolution simulation equation of reservoir damage by the water lock effect according to the permeability distribution equation and the aqueous phase motion equation, wherein the spatio-temporal evolution simulation equation is used to simulate a four-dimensional spatio-temporal evolution process of characteristics of reservoir damage caused by the water lock effect.

6. The method for determining the damage extent of the reservoir according to claim 2 , further comprising: determining a spatio-temporal evolution simulation equation of reservoir damage by the inorganic precipitation by the following modeling process:
determining a Darcy apparent velocity of a fluid in the reservoir;
determining an ion concentration loss corresponding to each of a plurality of ions in an extraneous fluid, wherein the ion concentration loss is caused by a precipitation reaction between each of the ions and a corresponding ion in the fluid in the reservoir;
establishing a migration equation for each of the ions according to the Darcy apparent velocity of the fluid

Assignees

• Univ China Petroleum Beijing
• Cnpc Chuanqing Drilling Eng Co
• Cnpc Eng Tech Res & Dev Co Ltd

Inventors

• Jiang Guancheng
• He Yinbo
• Dong tengfei
• Peng Chunyao
• Yang Lili
• Luo Xiaohu
• Luo Xuwu
• Liang Xing
• Tan Bin
• Wang Yong
• Fu Daqi
• Geng Tie
• Ran Qihua
• Liu Xiaobo
• Cheng Rongchao
• Wang Zenglin
• Chen Gang
• Zhu Honghao
• Li Yizheng
• Zhao Li
• Cui Kaixiao

Classifications

• G01N13/00

  Investigating surface or boundary effects, e.g. wetting power; Investigating diffusion effects; Analysing materials by determining surface, boundary, or diffusion effects (scanning-probe techniques or apparatus G01Q) · CPC title

• G01N2013/003

  Diffusion; diffusivity between liquids · CPC title

• E21B43/20

  Displacing by water · CPC title

• E21B47/06

  Measuring temperature or pressure · CPC title

• G01N15/0826

  and measuring fluid flow rate, i.e. permeation rate or pressure change · CPC title