CN117371345A - Liquid holdup calculation method for gas well - Google Patents

Liquid holdup calculation method for gas well Download PDF

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Publication number
CN117371345A
CN117371345A CN202311275861.6A CN202311275861A CN117371345A CN 117371345 A CN117371345 A CN 117371345A CN 202311275861 A CN202311275861 A CN 202311275861A CN 117371345 A CN117371345 A CN 117371345A
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liquid
gas
coefficient
holdup
gas well
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王小勇
李娅琪
邱勇
沈威
徐立
刘若虚
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China Petroleum and Chemical Corp
Sinopec Henan Oilfield Branch Co
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China Petroleum and Chemical Corp
Sinopec Henan Oilfield Branch Co
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    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06F—ELECTRIC DIGITAL DATA PROCESSING
    • G06F30/00—Computer-aided design [CAD]
    • G06F30/20—Design optimisation, verification or simulation
    • G06F30/28—Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06F—ELECTRIC DIGITAL DATA PROCESSING
    • G06F2113/00—Details relating to the application field
    • G06F2113/08—Fluids
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06F—ELECTRIC DIGITAL DATA PROCESSING
    • G06F2113/00—Details relating to the application field
    • G06F2113/14—Pipes
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06F—ELECTRIC DIGITAL DATA PROCESSING
    • G06F2119/00—Details relating to the type or aim of the analysis or the optimisation
    • G06F2119/08—Thermal analysis or thermal optimisation
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06F—ELECTRIC DIGITAL DATA PROCESSING
    • G06F2119/00—Details relating to the type or aim of the analysis or the optimisation
    • G06F2119/14—Force analysis or force optimisation, e.g. static or dynamic forces
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
    • Y02P90/30—Computing systems specially adapted for manufacturing

Abstract

The invention relates to a method for calculating the liquid holdup of a gas well, and belongs to the technical field of oil and gas field development. The method comprises the steps of obtaining production data of a target gas well, wherein the production data comprise gas apparent flow rate, liquid apparent flow rate, gas density, liquid viscosity, gas-liquid surface tension, node average pressure and gas well pipe diameter, substituting the obtained data of the production data into a fitting relation between a liquid holdup coefficient and a first algebraic formula and a fitting relation between a correction coefficient and a second algebraic formula respectively to obtain the liquid holdup coefficient and the correction coefficient, and obtaining the liquid holdup of the target gas well through the product of the liquid holdup coefficient and the correction coefficient.

Description

Liquid holdup calculation method for gas well
Technical Field
The invention relates to a method for calculating the liquid holdup of a gas well, and belongs to the technical field of oil and gas field development.
Background
The gas well with high water-gas ratio is a gas well with high air humidity, and liquid accumulation can be inevitably generated at a low-lying position of a pipeline in the running process of the pipeline of the gas well with high water-gas ratio. The presence of liquid accumulation can induce a number of safety problems, and even accidents in severe cases. Therefore, accurate calculation of hydraulic characteristic parameters such as liquid holdup is critical to planning and running of the gas-liquid two-phase flow pipeline, and accurate prediction, prevention and treatment of any phenomenon of obstructing fluid flow in an oil and gas production and transportation system can be performed only by sufficiently and accurately calculating the liquid holdup of the pipeline, so that the safe and normal running of the pipeline is ensured.
The current research on the liquid holdup is to deduce a liquid holdup function related to the liquid film thickness and the liquid holdup according to the liquid drop entrainment rate, the gas phase apparent flow rate and the liquid phase apparent flow rate, although the liquid holdup function can be obtained by the method, the influence factors such as gas density, liquid density, pipe diameter and pressure are not considered, and the liquid holdup is not accurate because the liquid holdup is calculated by considering the liquid drop entrainment rate, the gas phase apparent flow rate, the liquid phase apparent flow rate, the gas density, the liquid density and the gas-liquid surface tension in the paper 'horizontal gas well gas-liquid two-phase pipe flow pressure drop prediction', so as to construct a 3-point curve representation liquid holdup variation expression along with the gas flow rate, and the method only considers the apparent flow rate of two phases and the tension of the density surface, but the liquid holdup is also influenced by the pressure and other reasons.
Disclosure of Invention
The invention aims to provide a method for calculating the liquid holdup of a gas well, which is used for solving the problem that the accuracy of the liquid holdup calculation result of the gas well with high water-gas ratio is low.
In order to achieve the above object, the present invention provides a method comprising:
the invention relates to a method for calculating the liquid holdup of a gas well, which comprises the following steps:
1) Obtaining production data of a target gas well, wherein the production data comprise gas apparent flow rate, liquid apparent flow rate, gas density, liquid viscosity, gas-liquid surface tension, node average pressure and gas well pipe diameter;
2) Substituting the obtained data of the production data into a fitting relation between the liquid holdup coefficient and the first algebraic expression to obtain the liquid holdup coefficient, substituting the obtained data of the production data into a fitting relation between the correction coefficient and the second algebraic expression to obtain the correction coefficient, and obtaining the liquid holdup of the target gas well through the product of the liquid holdup coefficient and the correction coefficient;
the fitting relation between the liquid holdup coefficient and the first expression is obtained by fitting the gas apparent flow rate, the liquid apparent flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension, the node average pressure and the gas well pipe diameter which are obtained by analog measurement and the corresponding liquid holdup coefficient; the fitting relation between the correction coefficient and the second algebraic expression is obtained by fitting the simulated measured gas apparent flow rate, gas density, liquid viscosity, gas-liquid surface tension and gas well pipe diameter with the corresponding correction coefficient.
The beneficial effects are that: according to the method for calculating the liquid holdup of the gas well, various factors such as the apparent gas flow rate, the apparent liquid flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension, the node average pressure and the pipe diameter are considered, the simulation result of the liquid holdup coefficient and the simulation result of the correction coefficient are correspondingly obtained through simulating the apparent gas flow rate, the apparent liquid flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension, the node average pressure and the pipe diameter, the fitting relation between the first generation expression and the liquid holdup coefficient is obtained through fitting again, the fitting relation between the second generation expression and the correction coefficient is obtained through substituting the obtained data into the first generation expression and the second generation expression respectively, the liquid holdup coefficient and the correction coefficient are obtained, and then the liquid holdup is calculated by combining various factors. The method is simple, convenient and accurate in calculation mode and high in applicability.
Further, the fitting relation between the first expression and the liquid holdup coefficient is obtained by: constructing a two-phase flow model according to the well body structure data of the target gas well and the equal proportion of the oil pipe size, and simulating and measuring the liquid viscosity, the gas-liquid surface tension, the node average pressure, the gas density, the liquid density and the liquid holdup coefficient in the well shaft in the two-phase flow model by setting the gas running speed, the liquid running speed, the gas well pressure, the temperature and the gas well diameter; and respectively changing one parameter of gas operation speed, liquid operation speed, gas well pressure, temperature and gas well pipe diameter, sequentially simulating and measuring liquid viscosity, gas-liquid surface tension, node average pressure, gas density, liquid density and liquid holdup coefficient in the well bore, and fitting the simulation result of the liquid holdup coefficient with a first coefficient to obtain a fitting relation of the liquid holdup coefficient and the first coefficient.
Further, the fitting relation between the second algebraic expression and the correction coefficient is obtained by: constructing a two-phase flow model according to the well body structural data of the target gas well and the oil pipe size in equal proportion, and simulating and measuring the liquid viscosity, the gas-liquid surface tension, the node average pressure, the gas density, the liquid density and the correction coefficient in the well shaft according to the set gas operation speed, the set liquid operation speed, the set gas well pressure, the set temperature and the set gas well diameter in the two-phase flow model; and respectively changing one parameter of the gas operation speed, the liquid operation speed, the gas well pressure, the temperature and the gas well pipe diameter, sequentially performing simulation measurement to correspondingly obtain the liquid viscosity, the gas-liquid surface tension, the node average pressure, the gas density, the liquid density and the correction coefficient in the well bore, and performing fitting by using the simulation result of the correction coefficient and a second algebraic formula to obtain a fitting relation of the correction coefficient and the second algebraic formula.
Further, the fitting relation between the first expression and the liquid holdup coefficient is:
in the method, in the process of the invention,for the liquid holdup coefficient, A is the first number, a 0 -a 4 Fitting coefficients are respectively used.
Further, the fitting relation between the second algebraic expression and the correction coefficient is:
in the method, in the process of the invention,for correction coefficients, B is a second-generation expression, B 0 -b 5 Fitting coefficients are respectively used.
Further, the first expression is obtained by fitting the gas apparent flow rate, the liquid apparent flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension, the node average pressure and the gas well pipe diameter obtained by analog measurement with the corresponding liquid holdup coefficient.
Further, the second expression is obtained by fitting the gas apparent flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension and the gas well pipe diameter obtained by analog measurement with corresponding correction coefficients.
Further, the first generation of formulas are:
wherein A is a first-generation expression, P is a node average pressure, and sc pressure in standard state, v sg V is the apparent flow rate of the gas phase sl Is apparent flow velocity of liquid phase, sigma is surface tension of gas liquid, D is inner diameter of gas well pipe, ρ l Is the density of the liquid phase mixture, mu l Is the viscosity of the liquid phase mixture x 1 -x 5 Are constant coefficients.
Further, the second algebraic formula is:
wherein B is a second-generation formula, mu l Is the viscosity of the liquid phase mixture, v sg Is the apparent flow rate of gas phase ρ g Is the density of the gas phase mixture, D is the inner diameter of a gas well pipe, ρ l Is the density of the liquid phase mixture, sigma is the surface tension of gas and liquid, y 1 -y 4 Are constant coefficients.
Drawings
FIG. 1 is a schematic illustration of a technical analytical route for calculation of liquid holdup for a gas well in an embodiment of the method of the present invention;
figure 2 is a schematic of liquid holdup at different depths in an embodiment of the method of the present invention.
Detailed Description
The invention is described in further detail below with reference to the accompanying drawings.
Liquid holdup calculation method embodiment of gas well:
according to the method for calculating the liquid holdup of the gas well, the influence of various factors such as gas apparent flow rate, liquid apparent flow rate, gas density, liquid viscosity, gas-liquid surface tension, node average pressure and pipe diameter on the liquid holdup is considered, and the scheme is obtained by researching a large amount of data such as different gas well gas operation speeds, liquid operation speeds, pressures, temperatures and pipe diameters, wherein the specific research thinking is as follows:
as shown in fig. 1, firstly, gas well production data and gas well body structure data are required to be obtained, wherein the gas well production data comprise bottom hole pressure, wellhead oil pressure, gas production, density and viscosity of gas, density and viscosity of water and inner diameter of oil pipe; the well bore structure data includes sounding, hanging and beveling.
And secondly, constructing a visual two-phase flow experimental device (or a two-phase flow model) according to the actual oil pipe size, the well structure of the gas well and the like.
And then, inputting the set different gas operation speeds, liquid operation speeds, gas densities, liquid densities and different gas well pipelines into a visual two-phase flow experimental device (or a two-phase flow model), and simulating to obtain the corresponding liquid viscosity, gas-liquid surface tension, node average pressure, liquid holdup coefficient and correction coefficient under the different gas operation speeds, liquid operation speeds, gas densities, liquid densities and pipeline diameters. The method comprises the following specific steps:
1) Giving a gas and liquid running speed, pressure, temperature and pipe diameter, and obtaining liquid viscosity, gas and liquid surface tension, node average pressure, gas density, liquid holdup coefficient and correction coefficient under different gas running speeds, liquid running speeds, pressures, temperatures and pipe diameters through simulation measurement;
2) Changing the gas operation speed, and repeating the step 1);
3) Changing the running speed of the liquid, and repeating the steps 1) to 2);
4) Changing the pressure, and repeating the steps 1) to 3);
5) Changing the temperature, and repeating the steps 1) to 4);
6) Changing the pipe diameter, and repeating the steps 1) to 5).
According to the operation, through the obtained simulation results of the viscosity, the gas-liquid surface tension, the node average pressure, the gas density, the liquid holdup coefficient and the correction coefficient in the corresponding shaft under different gas operation speeds, liquid operation speeds, pressures, temperatures and pipe diameters, a first-generation expression (assuming that the expression is A) consisting of eight variables of the liquid holdup coefficient and the gas apparent flow rate, the liquid apparent flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension, the node average pressure and the pipe diameter has a multi-element curve fitting relation, wherein the first-generation expression is an empirical formula, and the expression is:
wherein A is a first-generation expression,is the average pressure of the node, P sc Pressure in standard state, v sg V is the apparent flow rate of the gas phase sl Is apparent flow velocity of liquid phase, sigma is surface tension of gas liquid, D is inner diameter of gas well pipe, ρ l Is the density of the liquid phase mixture, mu l Is the viscosity of the liquid phase mixture x 1 -x 5 Are constant coefficients, where the constant coefficients are constants set in the expression. Wherein the first coefficient is the constant coefficient x 1 -x 5 Respectively set as x 1 ＝0.39375、x 2 ＝0.25、x 3 ＝0.575、x 4 ＝0.14375、x 5 ＝1.747。
Fitting is carried out by utilizing the first generation expression and the liquid holdup coefficient in the simulation result, so as to obtain a relation expression between the first generation expression and the liquid holdup coefficient:
in the method, in the process of the invention,for the liquid holdup coefficient, A is the first number, a 0 -a 4 Respectively fitting coefficients, wherein a 4 ＝-2×10 9 ，a 3 ＝4×10 7 ，a 2 ＝-338204，a 1 ＝1240.6，a 0 ＝-1.6392。
According to simulation results of the obtained values of the viscosity, the gas-liquid surface tension, the node average pressure, the gas density, the liquid holdup coefficient and the correction coefficient of the well bore under different gas running speeds, liquid running speeds, pressures, temperatures and pipe diameters, a multi-element curve relationship exists between the correction coefficient and a second expression (assuming that the expression is B) consisting of six variables of the gas apparent flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension and the pipe diameter, wherein the second expression is an empirical formula, and the expression is as follows:
wherein B is a second-generation formula, mu l Is the viscosity of the liquid phase mixture, v sg Is the apparent flow rate of gas phase ρ g Is the density of the gas phase mixture, D is the inner diameter of a gas well pipe, ρ l Is the density of the liquid phase mixture, sigma is the surface tension of gas and liquid, y 1 -y 4 Are constant coefficients, which are constants set in the expression. Wherein the constant coefficients of the constant coefficients B of the second algebraic expression are y respectively 1 ＝0.38、y 2 ＝0.25、y 3 ＝0.595、y 4 ＝0.035。
Fitting is carried out by using the second algebraic formula and the correction coefficient in the simulation result, so as to obtain a relational expression between the second algebraic formula and the correction coefficient:
in the method, in the process of the invention,for correction coefficients, B is a second-generation expression, B 0 -b 5 Respectively the fitting coefficients, and b of the formula in the present embodiment 5 ＝-10 7 ，b 4 ＝3×10 6 ，b 3 ＝-325637，b 2 ＝14487，b 1 ＝-271.51，b 0 ＝2.8077。
Based on the above research discovery process, the fitting relation between the liquid holdup coefficient and the first expression and the fitting relation between the correction coefficient and the second expression are obtained through analysis, and the liquid holdup required in the embodiment can be obtained based on the fitting relation between the liquid holdup coefficient and the first expression and the fitting relation between the correction coefficient and the second expression, and the specific implementation manner is as follows:
1) Obtaining production data of a target gas well, wherein the production data comprise gas apparent flow rate, liquid apparent flow rate, gas density, liquid viscosity, gas-liquid surface tension, node average pressure and gas well pipe diameter;
2) Substituting the obtained data of the production data into a fitting relation between the liquid holdup coefficient and the first algebraic expression to obtain the liquid holdup coefficient, substituting the obtained data of the production data into a fitting relation between the correction coefficient and the second algebraic expression to obtain the correction coefficient, and obtaining the liquid holdup of the target gas well through the product of the liquid holdup coefficient and the correction coefficient;
the fitting relation between the liquid holdup coefficient and the first expression is obtained by fitting the gas apparent flow rate, the liquid apparent flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension, the node average pressure and the gas well pipe diameter which are obtained by analog measurement and the corresponding liquid holdup coefficient; the fitting relation between the correction coefficient and the second algebraic expression is obtained by fitting the gas apparent flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension and the gas well pipe diameter which are obtained through analog measurement and the corresponding correction coefficient.
Wherein the first and second generation expressions are empirical formulas, and the first generation expression is:
in the middle ofIs the average pressure of the node, and the unit is Mpa; p is p sc Is the pressure in standard state, the unit is MPa, p is taken sc 0.101MPa；v sg Is the apparent flow rate of the gas phase, and the unit is m/s; the method comprises the steps of carrying out a first treatment on the surface of the v sl Is the apparent flow rate of the liquid phase, and the unit is m/s; sigma is the gas-liquid surface tension, and the unit is N/m; d is the inner diameter of the tube, m; ρ l Is the density of the liquid phase mixture, and the unit is kg/m 3 ；ρ g Is the density of the gas phase mixture, the unit is kg/m 3 ；μ l Is the viscosity of the liquid phase mixture, and the unit is Pa.s. The second expression is:
wherein B is a second-generation formula, mu l Viscosity of liquid phase mixture, v sg Is the apparent flow rate of gas phase ρ g Is the density of the gas phase mixture, D is the inner diameter of a gas well pipe, ρ l For the density of the liquid phase mixture, σ is the gas-liquid surface tension.
Specifically, the constant coefficient of the first-generation expression is set to x 1 ＝0.39375、x 2 ＝0.25、x 3 ＝0.575、x 4 ＝0.14375、x 5 =1.747, where the first expression is:
the constant coefficient of the second code is set as y 1 ＝0.38、y 2 ＝0.25、y 3 ＝0.595、y 4 =0.035, where the second expression is:
the first coefficient A and the liquid holdup coefficient established in the embodimentThe fitting relation of (2) is as follows:
the second generation number B and the correction coefficient are establishedThe fitting relation of (2) is as follows:
according to the product of the liquid holdup coefficient and the correction coefficient in the embodiment, the liquid holdup H of the gas well with high water-gas ratio can be calculated 1 Formula H for calculating liquid holdup 1 The following are provided:
according to the target gas well structure data and the oil pipe size equal proportion, a two-phase flow model is constructed, and in the two-phase flow model, the gas operation speed, the liquid operation speed, the gas well pressure, the temperature and the gas well pipe diameter are set, and the liquid viscosity, the gas-liquid surface tension, the node average pressure, the gas density, the liquid density and the liquid holdup coefficient in a well shaft are simulated and measured; and respectively changing one parameter of gas operation speed, liquid operation speed, gas well pressure, temperature and gas well pipe diameter, sequentially simulating and measuring liquid viscosity, gas-liquid surface tension, node average pressure, gas density, liquid density and liquid holdup coefficient in the well bore, fitting the simulation result to obtain a first-generation formula, and fitting the simulation result of the liquid holdup coefficient with the first-generation formula to obtain a fitting relation of the liquid holdup coefficient and the first-generation formula. And the second algebraic expression can be obtained by the same way, and the fitting relation between the correction coefficient and the second algebraic expression is obtained by fitting the simulation result of the correction coefficient and the second algebraic expression.
Because the liquid holdup coefficient in this embodiment can be expressed using a first expression, the first expression has a fitting relationship with the gas apparent flow rate, the liquid apparent flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension, the node average pressure, and the gas well pipe diameter; the correction coefficient can be expressed by a second algebraic expression, and the second algebraic expression has a fitting relation with the gas apparent flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension and the gas well pipe diameter, so that the fitting relation between the liquid holdup and the gas apparent flow rate, the liquid apparent flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension, the node average pressure and the pipe diameter in the embodiment can be obtained, and the liquid holdup of the gas well as shown in fig. 2 can be accurately calculated by obtaining the gas apparent flow rate, the liquid apparent flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension, the node average pressure and the pipe diameter of the gas well.

Claims (9)

1. The method for calculating the liquid holdup of the gas well is characterized by comprising the following steps of:
1) Obtaining production data of a target gas well, wherein the production data comprise gas apparent flow rate, liquid apparent flow rate, gas density, liquid viscosity, gas-liquid surface tension, node average pressure and gas well pipe diameter;
2) Substituting the obtained data of the production data into a fitting relation between the liquid holdup coefficient and the first algebraic expression to obtain the liquid holdup coefficient, substituting the obtained data of the production data into a fitting relation between the correction coefficient and the second algebraic expression to obtain the correction coefficient, and obtaining the liquid holdup of the target gas well through the product of the liquid holdup coefficient and the correction coefficient;
the fitting relation between the liquid holdup coefficient and the first expression is obtained by fitting the gas apparent flow rate, the liquid apparent flow rate, the gas density, the liquid viscosity, the gas-liquid surface tension, the node average pressure and the gas well pipe diameter which are obtained by analog measurement and the corresponding liquid holdup coefficient; the fitting relation between the correction coefficient and the second algebraic expression is obtained by fitting the simulated measured gas apparent flow rate, gas density, liquid viscosity, gas-liquid surface tension and gas well pipe diameter with the corresponding correction coefficient.
2. The method for calculating the liquid holdup of a gas well according to claim 1, wherein the fitting relation between the first numerical expression and the liquid holdup coefficient is obtained by: constructing a two-phase flow model according to the well body structure data of the target gas well and the equal proportion of the oil pipe size, and simulating and measuring the liquid viscosity, the gas-liquid surface tension, the node average pressure, the gas density, the liquid density and the liquid holdup coefficient in the well shaft in the two-phase flow model by setting the gas running speed, the liquid running speed, the gas well pressure, the temperature and the gas well diameter; and respectively changing one parameter of gas operation speed, liquid operation speed, gas well pressure, temperature and gas well pipe diameter, sequentially simulating and measuring liquid viscosity, gas-liquid surface tension, node average pressure, gas density, liquid density and liquid holdup coefficient in the well bore, and fitting the simulation result of the liquid holdup coefficient with a first coefficient to obtain a fitting relation of the liquid holdup coefficient and the first coefficient.
3. The method for calculating the liquid holdup of a gas well according to claim 1, wherein the fitting relation between the second algebraic expression and the correction coefficient is obtained by: constructing a two-phase flow model according to the well body structural data of the target gas well and the oil pipe size in equal proportion, and simulating and measuring the liquid viscosity, the gas-liquid surface tension, the node average pressure, the gas density, the liquid density and the correction coefficient in the well shaft according to the set gas operation speed, the set liquid operation speed, the set gas well pressure, the set temperature and the set gas well diameter in the two-phase flow model; and respectively changing one parameter of the gas operation speed, the liquid operation speed, the gas well pressure, the temperature and the gas well pipe diameter, sequentially performing simulation measurement to correspondingly obtain the liquid viscosity, the gas-liquid surface tension, the node average pressure, the gas density, the liquid density and the correction coefficient in the well bore, and performing fitting by using the simulation result of the correction coefficient and a second algebraic formula to obtain a fitting relation of the correction coefficient and the second algebraic formula.
4. The method for calculating the liquid holdup of a gas well according to claim 2, wherein the fitting relation of the first numerical expression and the liquid holdup coefficient is:
in the method, in the process of the invention,for the liquid holdup coefficient, A is the first number, a 0 -a 4 Fitting coefficients are respectively used.
5. A method of calculating the liquid holdup of a gas well as claimed in claim 3, wherein the fit relationship of the second algebraic equation to the correction factor is:
in the method, in the process of the invention,for correction coefficients, B is a second-generation expression, B 0 -b 5 Fitting coefficients are respectively used.
6. The method for calculating the liquid holdup of a gas well according to claim 4, wherein the first expression is obtained by fitting the simulated measured gas apparent flow rate, liquid apparent flow rate, gas density, liquid viscosity, gas-liquid surface tension, node average pressure and gas well pipe diameter with the corresponding liquid holdup coefficients.
7. The method for calculating the liquid holdup of a gas well according to claim 5, wherein the second algebraic formula is obtained by fitting the simulated measured gas apparent flow rate, gas density, liquid viscosity, gas-liquid surface tension and gas well pipe diameter with corresponding correction coefficients.
8. The method of calculating the liquid holdup of a gas well according to claim 6, wherein the first numerical formula is:
wherein A is a first-generation expression,is the average pressure of the node, P sc Pressure in standard state, v sg V is the apparent flow rate of the gas phase sl Is apparent flow velocity of liquid phase, sigma is surface tension of gas liquid, D is inner diameter of gas well pipe, ρ l Is the density of the liquid phase mixture, mu l Is the viscosity of the liquid phase mixture x 1 -x 5 Are constant coefficients.
9. The method of calculating the liquid holdup of a gas well according to claim 7, wherein the second algebraic formula is:
wherein B is a second-generation formula, mu l Viscosity of liquid phase mixture, v sg Is the apparent flow rate of gas phase ρ g Is the density of the gas phase mixture, D is the inner diameter of a gas well pipe, ρ l Is the density of the liquid phase mixture, sigma is the surface tension of gas and liquid, y 1 -y 4 Are constant coefficients.
CN202311275861.6A 2023-09-28 2023-09-28 Liquid holdup calculation method for gas well Pending CN117371345A (en)

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