CN111563307B

CN111563307B - Working parameter configuration method and device of gas injection equipment

Info

Publication number: CN111563307B
Application number: CN201910078619.7A
Authority: CN
Inventors: 程海鹰; 李辉; 陈瑜芳; 章杨; 张祝新; 张传干; 张�杰; 蔡明俊
Original assignee: Petrochina Co Ltd
Current assignee: Petrochina Co Ltd
Priority date: 2019-01-28
Filing date: 2019-01-28
Publication date: 2022-11-04
Anticipated expiration: 2039-01-28
Also published as: CN111563307A

Abstract

The invention discloses a working parameter configuration method and device of gas injection equipment, and belongs to the technical field of gas drive oil production. The method comprises the following steps: acquiring target bottom hole flowing pressure based on various parameters of an oil well and a bottom hole flowing pressure calculation model; on the basis, the pressure of the lower end of each well barrel section is sequentially obtained based on the differential pressure calculation model of each well barrel section, and finally the gas injection pressure of the wellhead of the oil well is obtained; configuring working parameters of gas injection equipment based on the wellhead gas injection pressure; injecting gas into the well. The above-mentioned process obtains well head gas injection pressure based on predetermineeing shaft bottom flowing pressure and each item parameter of oil well, and is quick simple and convenient, has avoided using gas injection compressor and relevant corollary equipment to test, has also avoided complicated implementation process, can dispose the working parameter of gas injection equipment fast, has promoted the efficiency of gas injection process, has also reduced the cost of gas injection process.

Description

Working parameter configuration method and device of gas injection equipment

Technical Field

The invention relates to the technical field of gas drive oil extraction, in particular to a working parameter configuration method and a working parameter configuration device of gas injection equipment.

Background

The gas-drive oil extraction mode is an oil extraction mode generally applied to deep low-permeability oil reservoirs, and during oil extraction by using the gas-drive mode, the working parameters of gas injection equipment need to be configured, so that the gas injection equipment injects gas into an oil well at a certain wellhead gas injection pressure, and the pressure of the oil reservoir meets the production requirement so as to facilitate oil production.

The method for configuring the working parameters of the conventional gas injection equipment comprises the steps of performing test injection by using a ground compressor, acquiring wellhead gas injection pressure and bottom gas injection pressure under different injection conditions, acquiring the required working parameters of the gas injection equipment according to the wellhead gas injection pressure and the bottom gas injection pressure, and configuring the gas injection equipment based on the working parameters.

Disclosure of Invention

The embodiment of the invention provides a working parameter configuration method and a working parameter configuration device for gas injection equipment, which can solve the problems that the working parameter configuration method of the conventional gas injection equipment needs to use a gas injection compressor and related supporting equipment for testing, the implementation process is complex, and the working parameters of the gas injection equipment cannot be rapidly configured. The technical scheme is as follows:

in one aspect, a method for configuring operating parameters of a gas injection apparatus is provided, the method comprising:

acquiring a target bottom flowing pressure based on basic oil reservoir parameters, injected gas parameters, gas injection key design parameters, a gas phase viscosity calculation model and a bottom flowing pressure calculation model of an oil well, wherein the basic oil reservoir parameters comprise formation temperature, oil layer depth, oil layer thickness and permeability, the injected gas parameters comprise the relative density of gas, the average compression factor of gas, the average relative molecular mass of gas and the temperature of an injected gas well mouth, and the gas injection key design parameters comprise preset oil reservoir pressure, well type, daily gas injection quantity on the ground, the inner diameter of an injected oil pipe and relative roughness;

dividing the oil well into a plurality of wellbore sections based on a preset step length;

sequentially acquiring the lower end pressure of each well barrel section based on the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter, the target bottom hole flowing pressure, the gas phase viscosity calculation model and the pressure difference calculation model of each well barrel section;

acquiring the upper end pressure of the uppermost wellbore section in the wellbore sections as the wellhead gas injection pressure of the oil well;

configuring working parameters of gas injection equipment based on the wellhead gas injection pressure;

and injecting gas into the oil well based on the configured gas injection equipment.

In one possible implementation, the method further comprises:

acquiring a first reservoir pressure in a gas injection process;

when the absolute value of the difference between the first reservoir pressure and the target reservoir pressure is not less than a first preset threshold value, adjusting the working parameters of the gas injection equipment to obtain a second reservoir pressure, so that the absolute value of the difference between the second reservoir pressure and the target reservoir pressure is less than the first preset threshold value.

In one possible implementation, the obtaining the target bottom hole flowing pressure based on the basic oil deposit parameters, the injected gas parameters, the gas injection key design parameters, the gas phase viscosity calculation model and the bottom hole flowing pressure calculation model comprises:

for any preset first bottom hole flowing pressure, acquiring first gas phase viscosity based on the first bottom hole flowing pressure, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the gas phase viscosity calculation model;

outputting a second bottom hole flowing pressure based on the first gas phase viscosity, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the bottom hole flowing pressure calculation model;

and when the absolute value of the difference between the second bottom hole flowing pressure and the preset bottom hole flowing pressure is not less than a second preset threshold value, acquiring the second bottom hole flowing pressure as the first bottom hole flowing pressure, and iterating until the absolute value of the difference between the output bottom hole flowing pressure and the preset bottom hole flowing pressure is less than the second preset threshold value, and acquiring the output bottom hole flowing pressure as the target bottom hole flowing pressure.

In one possible implementation, the sequentially obtaining the lower end pressure of each wellbore section based on the basic reservoir parameter, the injected gas parameter, the gas injection key design parameter, the target bottom hole flow pressure, the gas phase viscosity calculation model, and the differential pressure calculation model of each wellbore section comprises:

the method comprises the following steps of using i to represent the number of the wellbore sections, using N to represent the total number of the wellbore sections, wherein i is less than or equal to N, N is an integer greater than or equal to 1, and for any two adjacent ith wellbore section and (i + 1) th wellbore section, obtaining the lower end pressure of the (i + 1) th wellbore section according to the lower end pressure of the ith wellbore section comprises the following steps:

acquiring the gas phase viscosity of the lower end of the ith wellbore section based on the pressure of the lower end of the ith wellbore section, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the gas phase viscosity calculation model;

for any preset third lower end pressure of the (i + 1) th well barrel section, acquiring the gas phase viscosity of the (i + 1) th well barrel section based on the third lower end pressure, the target bottom hole flow pressure, the basic oil deposit parameter, the injected gas parameter, the gas injection key design parameter and the gas phase viscosity calculation model;

obtaining the average gas phase viscosity of the ith wellbore section based on the gas phase viscosity of the lower end of the ith wellbore section and the gas phase viscosity of the (i + 1) th wellbore section;

outputting the fourth lower end pressure of the (i + 1) th wellbore section based on the average gas phase viscosity of the ith wellbore section, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the differential pressure calculation model of the ith wellbore section;

when the absolute value of the difference between the fourth lower end pressure of the (i + 1) th wellbore section and the preset lower end pressure of the (i + 1) th wellbore section is not less than a third preset threshold, acquiring the fourth lower end pressure as the third lower end pressure, and performing iteration until the absolute value of the difference between the output lower end pressure and the preset lower end pressure is less than the third preset threshold, acquiring the output lower end pressure as the lower end pressure of the (i + 1) th wellbore section;

and sequentially obtaining the lower end pressure of each wellbore section based on the method for obtaining the lower end pressure of the (i + 1) th wellbore section from the lower end pressure of the ith wellbore section, the basic oil deposit parameters, the injected gas parameters, the gas injection key design parameters, the target bottom hole flowing pressure, the gas phase viscosity calculation model and the pressure difference calculation model of each wellbore section.

In one possible implementation, the downhole flow pressure calculation model includes:

the target bottom hole flowing pressure is obtained based on the following formulas I to IV:

the formula I is as follows:

the formula II is as follows:

the formula III is as follows:

the formula four is as follows:

wherein, P _wf Is the target bottom hole flowing pressure in MPa, P _e In order to preset reservoir pressure in MPa, Q _sc The daily gas injection amount on the ground is in Nm ³ And/d, T is the formation temperature in K,

is the average gas phase viscosity of the oil reservoir and the bottom of the well, and has the unit of mPas,

is the average compressibility factor, dimensionless, K is permeability in mD, h is the oil layer thickness in m, r _e Is the effective radius of the vertical well, and has the unit of m, r _w Is the radius of the oil interval borehole, and has the unit of m, s is a first skin coefficient, and has no dimension, DQ _sc Is the second skin factor, dimensionless,γ _g for relative density of injected gas, dimensionless, T _sc Is standard temperature in K, K _h Is the vertical permeability in mD, P _sc Is standard atmospheric pressure in MPa, a is a first parameter, L is the length of the horizontal section in m, delta is a deviation coefficient, r is a dimensionless value _eh Is the effective radius of the horizontal well in m.

In one possible implementation, the gas phase viscosity calculation model includes:

the gas phase viscosity is obtained based on the following formulas five to ten:

the formula five is as follows:

formula six:

the formula seven:

the formula eight:

the formula is nine: y =2.4-0.2X

The formula ten:

wherein, mu _g (i) Is the gas phase viscosity at the lower end of the ith well barrel section, the unit is mPa.s, e is a natural constant, A, X and Y are intermediate parameters, rho _g (i) Is the gas density at the lower end of the ith wellbore section in g/cm ³ ，γ _g For the relative density of the injected gas, P (i) is the pressure at the lower end of the ith wellbore section in MPa, T (i) is the temperature at the lower end of the ith wellbore section in K,

to average compression factor, dimensionless, M _g Mean relative molecular mass, dimensionless.

In one possible implementation, the differential pressure calculation model includes:

according to the pressure of the lower end of the ith wellbore section, acquiring the pressure of the lower end of the (i + 1) th wellbore section on the basis of the following formulas eleven to fourteen:

the formula eleven:

the formula twelve:

equation thirteen:

the formula fourteen:

wherein, P (i + 1) is the lower end pressure of the (i + 1) th well barrel section in MPa, P (i) is the lower end pressure of the (i) th well barrel section in MPa, e is a natural constant, S is an intermediate coefficient, f _m Is friction coefficient, dimensionless, Q _sc The daily gas injection amount on the ground is in Nm ³ /d，

Is the average formation temperature, in K,

d is the inner diameter of the injection oil pipe and has the unit of m, gamma _g Is the relative density of injected gas, and is dimensionless, delta H is a preset step length, the unit is m, g is the gravity acceleration, the unit is m/s ² Reynolds number at the lower end of the ith wellbore section, re (i), dimensionless, γ _g The relative density of the injected gas is a dimensionless,

is the average gas phase viscosity of the ith wellbore section in mPa s, f _m (i) The friction coefficient of the lower end of the ith wellbore section is dimensionless, and e/d is relative roughness and dimensionless.

In one aspect, an apparatus for configuring operating parameters of a gas injection device is provided, the apparatus comprising:

the system comprises a bottom-hole flowing pressure acquisition module, a gas-phase viscosity calculation model and a bottom-hole flowing pressure calculation model, wherein the bottom-hole flowing pressure acquisition module is used for acquiring target bottom-hole flowing pressure based on basic oil reservoir parameters, injected gas parameters, gas injection key design parameters, a gas-phase viscosity calculation model and the bottom-hole flowing pressure calculation model of an oil well, the basic oil reservoir parameters comprise formation temperature, oil layer depth, oil layer thickness and permeability, the injected gas parameters comprise relative density of gas, average compression factor of gas, average relative molecular mass of gas and injected gas wellhead temperature, and the gas injection key design parameters comprise preset oil reservoir pressure, well type, daily gas injection quantity on the ground, inner diameter of an injection oil pipe and relative roughness;

the shaft section module is used for dividing the oil well into a plurality of shaft sections based on a preset step length;

a lower end pressure obtaining module, configured to sequentially obtain a lower end pressure of each wellbore section based on the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter, the target bottom hole flowing pressure, the gas phase viscosity calculation model, and a pressure difference calculation model of each wellbore section;

the wellhead gas injection pressure acquisition module is used for acquiring the upper end pressure of the uppermost wellbore section in the wellbore sections as the wellhead gas injection pressure of the oil well;

the parameter configuration module is used for configuring the working parameters of the gas injection equipment based on the wellhead gas injection pressure;

and the gas injection module is used for injecting gas into the oil well based on the configured gas injection equipment.

In one possible implementation, the apparatus further includes:

the device comprises a reservoir pressure acquisition module, a gas injection module and a gas injection module, wherein the reservoir pressure acquisition module is used for acquiring first reservoir pressure in the gas injection process;

the parameter configuration module is further configured to adjust the working parameter of the gas injection device when the absolute value of the difference between the first reservoir pressure and the target reservoir pressure is not less than a first preset threshold, and obtain a second reservoir pressure, so that the absolute value of the difference between the second reservoir pressure and the target reservoir pressure is less than the first preset threshold.

In one possible implementation, the downhole flow pressure obtaining module is configured to:

In one possible implementation, the lower end pressure obtaining module is configured to:

using i to represent the number of the wellbore sections, using N to represent the total number of the wellbore sections, wherein i is less than or equal to N, N is an integer greater than or equal to 1, and for any two adjacent ith wellbore sections and (i + 1) th wellbore sections, obtaining the lower end pressure of the (i + 1) th wellbore section by the lower end pressure of the ith wellbore section comprises:

for any preset third lower end pressure of the (i + 1) th wellbore section, acquiring the gas phase viscosity of the (i + 1) th wellbore section based on the third lower end pressure, the target bottom hole flowing pressure, the basic oil deposit parameter, the injected gas parameter, the gas injection key design parameter and the gas phase viscosity calculation model;

acquiring the average gas phase viscosity of the ith wellbore section based on the gas phase viscosity of the lower end of the ith wellbore section and the gas phase viscosity of the (i + 1) th wellbore section;

outputting a fourth lower end pressure of the (i + 1) th well barrel section based on the average gas phase viscosity of the ith well barrel section, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and a differential pressure calculation model of the ith well barrel section;

and sequentially obtaining the lower end pressure of each well cylinder section based on the method for obtaining the lower end pressure of the (i + 1) th well cylinder section from the lower end pressure of the ith well cylinder section, the basic oil deposit parameter, the injected gas parameter, the gas injection key design parameter, the target bottom hole flowing pressure, the gas phase viscosity calculation model and the pressure difference calculation model of each well cylinder section.

the formula I is as follows:

the formula II is as follows:

the formula III is as follows:

the formula four is as follows:

wherein, P _wf Is the target bottom hole flowing pressure in MPa, P _e In order to preset reservoir pressure, in MPa, Q _sc The daily gas injection amount on the ground is in Nm ³ And/d, T is the formation temperature in K,

is the average gas phase viscosity of the oil reservoir and the bottom of the well, and has the unit of mPa & s,

is the average compressibility factor, dimensionless, K is the permeability in mD, h is the reservoir thickness in m, r _e Is the effective radius of the vertical well, and has the unit of m, r _w Is the radius of the oil interval borehole, the unit is m, s is a first skin coefficient, dimensionless, DQ _sc Is the second skin coefficient, dimensionless, gamma _g Relative density, dimensionless, T, of injected gas _sc Is standard temperature in K, K _h Is the vertical permeability in mD, P _sc Is standard atmospheric pressure in MPa, a is a first parameter, L is the length of the horizontal section in m, delta is a deviation coefficient, r is a dimensionless value _eh Is the effective radius of the horizontal well and is expressed in m.

the formula five is as follows:

the formula six:

the formula is seven:

the formula eight:

the formula is nine: y =2.4-0.2X

Formula ten:

wherein, mu _g (i) Is the gas phase viscosity at the lower end of the ith well barrel section, the unit is mPa.s, e is a natural constant, A, X and Y are intermediate parameters, rho _g (i) Is the gas density at the lower end of the ith wellbore section, and has the unit of g/cm ³ ，γ _g For the relative density of the injected gas, P (i) is the pressure at the lower end of the ith wellbore section in MPa, T (i) is the temperature at the lower end of the ith wellbore section in K,

the formula eleven:

equation twelve:

equation thirteen:

the formula fourteen is as follows:

wherein, P (i + 1) is the lower end pressure of the i +1 th well cylinder section in MPa, P (i) is the lower end pressure of the i-th well cylinder section in MPa, e is a natural constant, S is an intermediate coefficient, f _m Is friction coefficient, dimensionless, Q _sc The daily gas injection amount on the ground is in Nm ³ /d，

Is the average formation temperature, in K,

is the average compression factor, dimensionless, d is the inner diameter of the injection tubing in m, gamma _g Is the relative density of injected gas, and is dimensionless, delta H is a preset step length, the unit is m, g is the gravity acceleration, the unit is m/s ² Reynolds number at the lower end of the ith wellbore section of Re (i), dimensionless, γ _g The relative density of the injected gas is a dimensionless,

is the average gas phase viscosity of the ith wellbore section in units of mPa · s, f _m (i) The friction coefficient of the lower end of the ith wellbore section is dimensionless, and e/d is relative roughness and dimensionless.

The technical scheme provided by the embodiment of the invention has the following beneficial effects:

the method provided by the embodiment of the invention is characterized in that the target bottom hole flowing pressure is obtained based on the basic oil deposit parameters, the injected gas parameters, the gas injection key design parameters, the gas phase viscosity calculation model and the bottom hole flowing pressure calculation model of the oil well; on the basis, the pressure of the lower end of each well barrel section is sequentially obtained based on the differential pressure calculation model of each well barrel section, and finally the gas injection pressure of the wellhead of the oil well is obtained; configuring working parameters of gas injection equipment based on the wellhead gas injection pressure; and injecting gas into the oil well based on the configured gas injection equipment. Above-mentioned process acquires well head gas injection pressure based on presetting the shaft bottom flowing pressure and each item parameter of oil well, working parameter based on this well head gas injection pressure adjustment gas injection equipment carries out the gas injection, can be fast simple and convenient acquire the well head gas injection pressure that accords with the needs, avoided using gas injection compressor and relevant corollary equipment to test, the implementation process of complicacy has also been avoided, can dispose the working parameter of gas injection equipment fast, the efficiency of gas injection process has been promoted, the cost of gas injection process has also been reduced.

Drawings

In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the drawings required to be used in the description of the embodiments are briefly introduced below, and it is obvious that the drawings in the description below are only some embodiments of the present invention, and it is obvious for those skilled in the art that other drawings can be obtained according to the drawings without creative efforts.

FIG. 1 is a flowchart of a method for configuring operating parameters of a gas injection apparatus according to an embodiment of the present invention;

FIG. 2 is a flowchart of a method for configuring operating parameters of a gas injection apparatus according to an embodiment of the present invention;

FIG. 3 is a schematic structural diagram of an apparatus for configuring operation parameters of a gas injection apparatus according to an embodiment of the present invention;

fig. 4 is a schematic structural diagram of a computer device according to an embodiment of the present invention.

Detailed Description

To make the objects, technical solutions and advantages of the present invention more apparent, embodiments of the present invention will be described in detail with reference to the accompanying drawings.

FIG. 1 is a flowchart of a method for configuring operating parameters of a gas injection apparatus according to an embodiment of the present invention. The method can be applied to a computer device, and comprises the following steps:

101. and acquiring target bottom hole flowing pressure based on the basic oil deposit parameters, the injected gas parameters, the gas injection key design parameters, the gas phase viscosity calculation model and the bottom hole flowing pressure calculation model of the oil well.

Wherein, this basic oil reservoir parameter includes stratum temperature, oil reservoir degree of depth, oil reservoir thickness and permeability, and this gas injection parameter includes gaseous relative density, gaseous average compression factor, gaseous average relative molecular mass and the gas injection well head temperature of gas, and this gas injection key design parameter includes preset oil reservoir pressure, well type, the daily gas injection volume in ground, injection oil pipe internal diameter and relative roughness.

102. The well is divided into a plurality of wellbore sections based on a preset step length.

103. And sequentially acquiring the lower end pressure of each well barrel section based on the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter, the target bottom hole flowing pressure, the gas phase viscosity calculation model and the pressure difference calculation model of each well barrel section.

104. And acquiring the upper end pressure of the uppermost wellbore section in the wellbore sections as the wellhead gas injection pressure of the oil well.

105. And configuring the working parameters of the gas injection equipment based on the wellhead gas injection pressure.

106. And injecting gas into the oil well based on the configured gas injection equipment.

According to the method provided by the embodiment of the invention, the target bottom hole flowing pressure is obtained based on the basic oil deposit parameters, the injected gas parameters, the key gas injection design parameters, the gas phase viscosity calculation model and the bottom hole flowing pressure calculation model of the oil well; on the basis, the pressure of the lower end of each well barrel section is sequentially obtained based on the differential pressure calculation model of each well barrel section, and finally the gas injection pressure of the wellhead of the oil well is obtained; configuring working parameters of gas injection equipment based on the wellhead gas injection pressure; and injecting gas into the oil well based on the configured gas injection equipment. Above-mentioned process acquires well head gas injection pressure based on presetting the shaft bottom flowing pressure and each item parameter of oil well, working parameter based on this well head gas injection pressure adjustment gas injection equipment carries out the gas injection, the well head gas injection pressure that accords with needs that obtains that can be quick simple and convenient, avoided using gas injection compressor and relevant corollary equipment to test, the implementation process of complicacy has also been avoided, can dispose the working parameter of gas injection equipment fast, the efficiency of gas injection process has been promoted, the cost of gas injection process has also been reduced.

In one possible implementation, the method further comprises:

acquiring a first reservoir pressure in a gas injection process; when the absolute value of the difference between the first reservoir pressure and the target reservoir pressure is not less than a first preset threshold value, adjusting the working parameters of the gas injection equipment to obtain a second reservoir pressure, so that the absolute value of the difference between the second reservoir pressure and the target reservoir pressure is less than the first preset threshold value.

In one possible implementation, the obtaining the target bottom hole flowing pressure based on the basic oil deposit parameters, the injected gas parameters, the gas injection key design parameters, the gas phase viscosity calculation model and the bottom hole flowing pressure calculation model comprises: for any preset first bottom hole flowing pressure, acquiring first gas phase viscosity based on the first bottom hole flowing pressure, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the gas phase viscosity calculation model; outputting a second bottom hole flowing pressure based on the first gas phase viscosity, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the bottom hole flowing pressure calculation model; and when the absolute value of the difference between the second bottom hole flowing pressure and the preset bottom hole flowing pressure is not less than a second preset threshold value, acquiring the second bottom hole flowing pressure as the first bottom hole flowing pressure, and iterating until the absolute value of the difference between the output bottom hole flowing pressure and the preset bottom hole flowing pressure is less than the second preset threshold value, and acquiring the output bottom hole flowing pressure as the target bottom hole flowing pressure.

In one possible implementation, the sequentially obtaining the lower end pressure of each wellbore section based on the basic reservoir parameter, the injected gas parameter, the gas injection key design parameter, the target bottom hole flowing pressure, the gas phase viscosity calculation model, and the pressure difference calculation model of each wellbore section includes: using i to represent the number of the wellbore sections, using N to represent the total number of the wellbore sections, wherein i is less than or equal to N, N is an integer greater than or equal to 1, and for any two adjacent ith wellbore sections and (i + 1) th wellbore sections, obtaining the lower end pressure of the (i + 1) th wellbore section by the lower end pressure of the ith wellbore section comprises: acquiring the gas phase viscosity of the lower end of the ith wellbore section based on the pressure of the lower end of the ith wellbore section, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the gas phase viscosity calculation model; for any preset third lower end pressure of the (i + 1) th well barrel section, acquiring the gas phase viscosity of the (i + 1) th well barrel section based on the third lower end pressure, the target bottom hole flow pressure, the basic oil deposit parameter, the injected gas parameter, the gas injection key design parameter and the gas phase viscosity calculation model; obtaining the average gas phase viscosity of the ith wellbore section based on the gas phase viscosity of the lower end of the ith wellbore section and the gas phase viscosity of the (i + 1) th wellbore section; outputting the fourth lower end pressure of the (i + 1) th wellbore section based on the average gas phase viscosity of the ith wellbore section, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the differential pressure calculation model of the ith wellbore section; when the absolute value of the difference between the fourth lower end pressure of the (i + 1) th wellbore section and the preset lower end pressure of the (i + 1) th wellbore section is not smaller than a third preset threshold, acquiring the fourth lower end pressure as the third lower end pressure, and performing iteration until the absolute value of the difference between the output lower end pressure and the preset lower end pressure is smaller than the third preset threshold, acquiring the output lower end pressure as the lower end pressure of the (i + 1) th wellbore section; and sequentially obtaining the lower end pressure of each wellbore section based on the method for obtaining the lower end pressure of the (i + 1) th wellbore section from the lower end pressure of the ith wellbore section, the basic oil deposit parameters, the injected gas parameters, the gas injection key design parameters, the target bottom hole flowing pressure, the gas phase viscosity calculation model and the pressure difference calculation model of each wellbore section.

In one possible implementation, the downhole flow pressure calculation model includes: the target bottom hole flowing pressure is obtained based on the following formulas I to IV:

the formula I is as follows:

the formula II is as follows:

the formula III is as follows:

the formula IV is as follows:

is the average compressibility factor, dimensionless, K is permeability in mD, h is the oil layer thickness in m, r _e Is the effective radius of the vertical well, and has the unit of m, r _w Is the radius of the oil interval borehole, and has the unit of m, s is a first skin coefficient, and has no dimension, DQ _sc Is the second skin coefficient, dimensionless, gamma _g For relative density of injected gas, dimensionless, T _sc Is standard temperature in K, K _h Is the vertical permeability in mD, P _sc Is standard atmospheric pressure in MPa, a is a first parameter, L is the length of the horizontal section in m, delta is a deviation coefficient, r is a dimensionless value _eh Is the effective radius of the horizontal well in m.

In one possible implementation, the gas phase viscosity calculation model includes: the gas phase viscosity is obtained based on the following formula five to formula ten:

the formula five is as follows:

formula six:

the formula seven:

the formula eight:

the formula is nine: y =2.4-0.2X

Formula ten:

wherein, mu _g (i) Is the gas phase viscosity at the lower end of the ith well barrel section, the unit is mPa.s, e is a natural constant, A, X and Y are intermediate parameters, rho _g (i) Is the gas density at the lower end of the ith wellbore section in g/cm ³ ，γ _g In order to obtain the relative density of injected gas, P (i) is the pressure of the lower end of the ith well cylinder section in MPa, T (i) is the temperature of the lower end of the ith well cylinder section in K,

In one possible implementation, the differential pressure calculation model includes: according to the pressure of the lower end of the ith wellbore section, acquiring the pressure of the lower end of the (i + 1) th wellbore section based on the following formulas from eleven to fourteen:

the formula eleven:

equation twelve:

formula thirteen:

the formula fourteen:

Is the average formation temperature, in K,

is the average gas phase viscosity of the ith wellbore section in mPa s, f _m (i) The friction coefficient of the lower end of the ith wellbore section is dimensionless, and e/d is relative roughness dimensionless.

FIG. 2 is a flowchart of a method for configuring operating parameters of a gas injection apparatus according to an embodiment of the present invention. The method can be applied to a computer device, and comprises the following steps:

201. and acquiring target bottom hole flowing pressure based on the basic oil deposit parameters, the injected gas parameters, the gas injection key design parameters, the gas phase viscosity calculation model and the bottom hole flowing pressure calculation model of the oil well.

Wherein, the basic oil reservoir parameters comprise formation temperature, oil layer depth, oil layer thickness and permeability, the injected gas parameters comprise relative density of gas, average compression factor of gas, average relative molecular mass of gas and injected gas well head temperature, and the gas injection key design parameters comprise preset oilReservoir pressure, well type, daily gas injection quantity on the ground, inner diameter of injection oil pipe and relative roughness. The formation temperature is the temperature of the formation to be injected with gas, the unit can be K or C, the depth of the oil layer is the depth of the oil layer to be injected with gas, the unit can be m, the thickness of the oil layer is the thickness of the oil layer to be injected with gas, the unit can be m, the permeability represents the capacity of the rock to allow fluid to pass through under certain pressure difference, and the unit can be mD; the relative density of gas refers to the ratio of the density of the gas to the density of the air under the same pressure and temperature, dimensionless, the average compression factor of the gas refers to the deviation of the compressed actual gas from the compressed ideal gas in volume, dimensionless, the average relative molecular mass of the gas refers to the ratio of the mass of a certain amount of mixed gas to the amount of a substance, dimensionless, the temperature of an injected gas wellhead refers to the temperature of the wellhead to be injected with gas, the unit can be K or DEG C, the preset reservoir pressure refers to the preset reservoir pressure after gas injection, the unit can be MPa, the well type refers to the type of an oil well and comprises a diameter and a horizontal well, the daily gas injection amount on the ground refers to the volume of daily gas injection obtained based on the preset gas injection speed, and the unit can be Nm ³ And d, the inner diameter of the injection oil pipe is the inner diameter of the oil pipe to be injected with gas, the unit can be m, and the relative roughness is the ratio of the height of the rough protrusion of the pipe wall to the inner diameter of the oil pipe, and is dimensionless.

In this step 201, a target bottom-hole flowing pressure is obtained based on a preset reservoir pressure, so that a wellhead gas injection pressure obtained based on the target bottom-hole flowing pressure in a subsequent step is also matched with the preset reservoir pressure, that is, gas is injected into an oil well based on the wellhead gas injection pressure, so that the reservoir can reach the preset reservoir pressure.

In one possible implementation, the process of obtaining the target bottom hole flow pressure includes the following steps 2011-2013:

2011. and for any one preset first bottom hole flowing pressure, acquiring first gas phase viscosity based on the first bottom hole flowing pressure, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the gas phase viscosity calculation model. The gas phase viscosity is a physical quantity characterizing the viscosity of the gas to be injected into the well, and is an intermediate parameter for obtaining a target bottom hole flow pressure. Because the bottom hole flowing pressure and the gas phase viscosity have a corresponding relation and mutually influence, the first gas phase viscosity is obtained based on the preset first bottom hole flowing pressure, the second bottom hole flowing pressure corresponding to the first gas phase viscosity can be obtained based on the first gas phase viscosity, and whether the preset first bottom hole flowing pressure is accurate or not can be judged based on the second bottom hole flowing pressure so as to adjust the preset first bottom hole flowing pressure.

The calculation method of the gas phase viscosity may be different according to the nature of the gas to be injected, and this embodiment is not limited to this. For example, when the gas to be injected is natural gas, the following formulas five to nine may be used; when the gas to be injected is oxygen-reduced air, the following equation ten may be used.

the formula is five:

the formula six:

the formula is seven:

the formula eight:

the formula is nine: y =2.4-0.2X

Formula ten:

wherein, mu _g (i) Is the gas phase viscosity of the lower end of the ith wellbore section, the unit is mPa.s, e is a natural constant, A, X and Y are intermediate parameters, rho _g (i) Is the gas density at the lower end of the ith wellbore section in g/cm ³ ，γ _g For the relative density of the injected gas, P (i) is the pressure at the lower end of the ith wellbore section in MPa, T (i) is the temperature at the lower end of the ith wellbore section in K,

to average compression factor, dimensionless, M _g Mean relative molecular mass, dimensionless. The number represented by i is used to indicate the number of the corresponding wellbore section, for example, the wellbore sections may be numbered from bottom to top by positive integers from small to large, where the number of the lowermost wellbore is 1, the lower end pressure of the 1 st wellbore section is the bottom flowing pressure, and the upper end pressure of the uppermost wellbore is the wellhead gas injection pressure. The process of obtaining T (i) may be obtained in various ways, for example, directly through a well temperature test process, or may be obtained through a temperature profile of other similar oil wells, or may be obtained by combining the bottom hole temperature T (1) with the following formula fifteen, which is not limited in this embodiment.

The formula fifteen: t (i) = T (1) -1.5 (i-1)

2012. And outputting a second bottom hole flowing pressure based on the first gas phase viscosity, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the bottom hole flowing pressure calculation model.

Because the second bottom hole flowing pressure and the first gas phase viscosity have a corresponding relation, whether the first gas phase viscosity is accurate or not can be judged based on the second bottom hole flowing pressure, and then whether the preset first bottom hole flowing pressure is accurate or not is judged, so that the preset first bottom hole flowing pressure can be adjusted conveniently.

The method of calculating the bottom hole flowing pressure may be different according to the well type of the oil well to be injected, and this embodiment is not limited thereto. For example, when the well is a vertical well, the following equations one and two may be used; when the well is a horizontal well, the following equations three and four may be used. In step 2012, the obtained second bottom hole flow pressure is the target bottom hole flow pressure in the following formula, and the process of obtaining the second bottom hole flow pressure based on the bottom hole flow pressure calculation model is described below.

the formula I is as follows:

the formula II is as follows:

the formula III is as follows:

the formula IV is as follows:

wherein, P _wf Is the target bottom hole flowing pressure in MPa and P _e In order to preset reservoir pressure in MPa, Q _sc The daily gas injection amount on the ground is in Nm ³ D, T is the formation temperature in K,

is the average compressibility factor, dimensionless, K is the permeability in mD, h is the reservoir thickness in m, r _e Is the effective radius of the vertical well, and has the unit of m, r _w Is the radius of the oil interval borehole, and has the unit of m, s is a first skin coefficient, and has no dimension, DQ _sc Is the second skin coefficient, dimensionless, gamma _g Relative density, dimensionless, T, of injected gas _sc Is standard temperature in K, K _h Is the vertical permeability in mD, P _sc Is standard atmospheric pressure in MPa, a is a first parameter, L is the length of the horizontal section in mDelta is the coefficient of deviation, dimensionless, r _eh Is the effective radius of the horizontal well in m.

The accuracy of the second bottom hole flow pressure calculated based on the above steps 2011 and 2012 is to be verified. If the accuracy of the second bottom hole flowing pressure is not high enough, the preset first bottom hole flowing pressure needs to be adjusted so as to obtain the target bottom hole flowing pressure.

2013. And when the absolute value of the difference between the second bottom-hole flowing pressure and the preset bottom-hole flowing pressure is not smaller than a second preset threshold value, acquiring the second bottom-hole flowing pressure as the first bottom-hole flowing pressure, and iterating until the absolute value of the difference between the output bottom-hole flowing pressure and the preset bottom-hole flowing pressure is smaller than the second preset threshold value, and acquiring the output bottom-hole flowing pressure as the target bottom-hole flowing pressure.

Specifically, the process of one iteration includes steps 2011 to 2012: that is, when the absolute value of the difference between the second bottom hole flow pressure and the preset bottom hole flow pressure is not less than the second preset threshold, the bottom hole flow pressure output in the previous iteration process is input as the first bottom hole flow pressure into the current iteration process, step 2011 and step 2012 are executed again, the bottom hole flow pressure is output again, whether the absolute value of the difference between the bottom hole flow pressure output this time and the preset bottom hole flow pressure is less than the second preset threshold is verified, and the output bottom hole flow pressure is obtained as the target bottom hole flow pressure until the absolute value of the difference between the output bottom hole flow pressure and the preset bottom hole flow pressure is less than the second preset threshold.

202. The well is divided into a plurality of wellbore sections based on a preset step length.

The differential pressure calculation models corresponding to different depths in the oil well are different, and for more accurately calculating the differential pressure between the depths in the oil well, the shaft of the oil well needs to be divided into a plurality of shaft sections, and the shaft sections are numbered, so that the lower end pressure of the shaft sections is sequentially acquired based on the differential pressure calculation model of each shaft section. For example, the wellbore can be divided into N wellbore sections, where N is an integer greater than or equal to 1, and the wellbore sections are numbered from bottom to top by using positive integers from small to large, where the number of the wellbore at the lowermost end is 1, the lower end pressure of the 1 st wellbore section is the bottom-hole flowing pressure, and the upper end pressure of the wellbore section at the uppermost end is the wellhead gas injection pressure. For example, the well may be divided into N wellbore sections in set steps of 100 m.

203. And sequentially acquiring the lower end pressure of each well barrel section based on the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter, the target bottom hole flowing pressure, the gas phase viscosity calculation model and the pressure difference calculation model of each well barrel section.

The pressure difference calculation models can be used for calculating the lower end pressure of the wellbore section at the upper adjacent position based on the lower end pressure of a wellbore section in the wellbore, specifically, the (i + 1) th wellbore section is located at the upper adjacent position of the (i) th wellbore section, that is, the pressure difference calculation models can be used for calculating the lower end pressure of the (i + 1) th wellbore section based on the lower end pressure of the (i) th wellbore section, and so on, the lower end pressure of each wellbore section can be calculated from bottom to top based on the pressure difference calculation model and the bottom flow pressure of each wellbore section.

In one possible implementation, the process of sequentially obtaining the lower end pressure of each wellbore section comprises: for any two adjacent wellbore sections, the process of obtaining the lower end pressure of the (i + 1) th wellbore section from the lower end pressure of the ith wellbore section may be: acquiring the gas phase viscosity of the ith wellbore section; presetting third lower end pressure of the (i + 1) th well barrel section, and acquiring gas phase viscosity based on the lower end pressure; and outputting the fourth lower end pressure of the (i + 1) th well casing section through the gas phase viscosity of the (i) th well casing section, the gas phase viscosity of the (i + 1) th well casing section and the differential pressure calculation model of the (i) th well casing section, and outputting the required lower end pressure by adopting an iteration method. Specifically, the process includes the following steps 2031-2034:

2031. and acquiring the gas phase viscosity of the lower end of the ith wellbore section based on the pressure of the lower end of the ith wellbore section, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the gas phase viscosity calculation model.

And calculating the lower end pressure of the 2 nd wellbore section by the lower end pressure of the 1 st wellbore section, and repeating the steps to obtain the lower end pressure of each wellbore section.

2032. And for any preset third lower end pressure of the (i + 1) th well barrel section, acquiring the gas phase viscosity of the (i + 1) th well barrel section based on the third lower end pressure, the target bottom hole flow pressure, the basic oil deposit parameter, the injected gas parameter, the gas injection key design parameter and the gas phase viscosity calculation model.

And outputting the lower end pressure of the (i + 1) th wellbore section through a subsequent iterative calculation process, wherein the third lower end pressure is a preset lower end pressure value.

2033. Acquiring the average gas phase viscosity of the ith wellbore section based on the gas phase viscosity of the lower end of the ith wellbore section and the gas phase viscosity of the (i + 1) th wellbore section; and outputting the fourth lower end pressure of the (i + 1) th well barrel section based on the average gas phase viscosity of the (i) th well barrel section, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the differential pressure calculation model of the (i) th well barrel section.

Wherein the average gas phase viscosity of the ith wellbore section is the average of the gas phase viscosity of the lower end of the ith wellbore section and the gas phase viscosity of the (i + 1) th wellbore section.

2034. When the absolute value of the difference between the fourth lower end pressure of the (i + 1) th wellbore section and the preset lower end pressure of the (i + 1) th wellbore section is not less than a third preset threshold value, acquiring the fourth lower end pressure as the third lower end pressure, and performing iteration until the absolute value of the difference between the output lower end pressure and the preset lower end pressure is less than the third preset threshold value, acquiring the output lower end pressure as the lower end pressure of the (i + 1) th wellbore section.

And the preset lower end pressure in each iteration process is equal to a third lower end pressure preset in the initial process. The third preset threshold may be set as needed, and may be, for example, 0.01MPa.

The process of obtaining the lower end pressure of each wellbore section is similar to steps 2031 to 2034, and is not described herein again.

formula eleven:

equation twelve:

formula thirteen:

the formula fourteen:

Is the average formation temperature, in K,

d is the inner diameter of the injection oil pipe and has the unit of m, gamma _g In order to obtain the relative density of injected gas, the delta H is a preset step length in the unit of m, and g is the acceleration of gravity in the unit of m/s ² Re (i) mine at the lower end of the ith shaft sectionNuo number, dimensionless, gamma _g The relative density of the injected gas is a dimensionless,

The data may be as shown in table 1 with the temperature, gas density, gas phase viscosity, reynolds number, friction coefficient and lower end pressure for each wellbore section:

TABLE 1

204. And acquiring the upper end pressure of the uppermost wellbore section in the wellbore sections as the wellhead gas injection pressure of the oil well.

According to the step 203, when the lower end pressure of the uppermost wellbore section is obtained, the lower end pressure of the next wellbore section of the uppermost wellbore section, that is, the upper end pressure of the uppermost wellbore section, is calculated, and the upper end pressure of the uppermost wellbore section is obtained as the wellhead gas injection pressure of the oil well.

205. And configuring the working parameters of the gas injection equipment based on the wellhead gas injection pressure.

The process of configuring the operating parameters of the gas injection apparatus is used to optimize the design of the gas injection system in preparation for the gas injection process.

206. And injecting gas into the oil well based on the configured gas injection equipment.

During the gas injection process, various production parameters in the oil well need to be monitored in time.

207. During gas injection, a first reservoir pressure is obtained.

At the gas injection in-process, acquire this first oil reservoir pressure through well head gas injection pressure, this first oil reservoir pressure is used for verifying injects gas with this well head gas injection pressure into this oil well, whether the pressure that enables the oil reservoir meets the demands. Specifically, the process of obtaining the first reservoir pressure through the wellhead gas injection pressure is opposite to the sequence from the step 201 to the step 206, and mainly includes steps 2071 to 2073:

2071. and acquiring basic oil deposit parameters, injected gas parameters and gas injection key design parameters in the gas injection process of the oil well. Wherein, this basic oil reservoir parameter includes stratum temperature, oil reservoir degree of depth, oil reservoir thickness and permeability, and this gas injection parameter includes gaseous relative density, gaseous average compression factor, gaseous average relative molecular mass and the gas injection well head temperature of gas, and this gas injection key design parameter includes well type, the daily gas injection volume in ground, injection oil pipe internal diameter and relative roughness.

2072. And acquiring the bottom hole flowing pressure in the gas injection process based on basic oil reservoir parameters, injected gas parameters, gas injection key design parameters, a gas phase viscosity calculation model and a pressure difference calculation model in the gas injection process of the oil well.

2073. Based on bottom hole flowing pressure, basic oil deposit parameters, injected gas parameters and gas injection key design parameters in the gas injection process, first oil deposit pressure in the gas injection process is obtained, the first oil deposit pressure is obtained based on various parameters in an oil well in the gas injection process, and the first oil deposit pressure can be used for representing the actual pressure of the oil deposit.

208. When the absolute value of the difference between the first reservoir pressure and the target reservoir pressure is not smaller than a first preset threshold value, the working parameters of the gas injection equipment are adjusted to obtain a second reservoir pressure, so that the absolute value of the difference between the second reservoir pressure and the target reservoir pressure is smaller than the first preset threshold value.

The target reservoir pressure may be the same as or different from the preset reservoir pressure in step 201 according to actual needs, which is not limited in this embodiment.

In step 208, when the absolute value of the difference between the first reservoir pressure and the target reservoir pressure is not less than the first preset threshold, it indicates that the well mouth gas injection pressure is used to inject gas into the oil well, and the reservoir pressure cannot meet the requirement, and at this time, the well mouth gas injection pressure needs to be adjusted, so that the second reservoir pressure corresponding to the adjusted well mouth gas injection pressure meets the requirement. The adjusted target value of the wellhead gas injection pressure can be obtained according to the target reservoir pressure based on the basic reservoir parameters, the injected gas parameters and the key design parameters of gas injection in the gas injection process obtained in the above steps 201 to 206 and step 2071.

And adjusting the working parameters of the gas injection equipment based on the adjustment target value of the gas injection pressure of the wellhead until the absolute value of the difference between the obtained second reservoir pressure and the target reservoir pressure is smaller than the first preset threshold value, so that the reservoir pressure of the oil well is ensured to meet the requirement, and the next step of oil production is facilitated.

All the above optional technical solutions may be combined arbitrarily to form the optional embodiments of the present disclosure, and are not described herein again.

The method provided by the embodiment of the invention is characterized in that the target bottom hole flowing pressure is obtained based on the basic oil deposit parameters, the injected gas parameters, the gas injection key design parameters, the gas phase viscosity calculation model and the bottom hole flowing pressure calculation model of the oil well; on the basis, the pressure of the lower end of each well barrel section is sequentially obtained based on the differential pressure calculation model of each well barrel section, and finally the gas injection pressure of the wellhead of the oil well is obtained; configuring working parameters of gas injection equipment based on the wellhead gas injection pressure; and injecting gas into the oil well based on the configured gas injection equipment. Above-mentioned process acquires well head gas injection pressure based on presetting the shaft bottom flowing pressure and each item parameter of oil well, working parameter based on this well head gas injection pressure adjustment gas injection equipment carries out the gas injection, the well head gas injection pressure that accords with needs that obtains that can be quick simple and convenient, avoided using gas injection compressor and relevant corollary equipment to test, the implementation process of complicacy has also been avoided, can dispose the working parameter of gas injection equipment fast, the efficiency of gas injection process has been promoted, the cost of gas injection process has also been reduced.

Furthermore, the method can also be used for monitoring the pressure of the oil reservoir in the gas injection process in real time, and the gas injection process is timely adjusted based on the pressure of the oil reservoir, so that the pressure of the oil reservoir meets the requirement. The method has the advantages of wide application range, complete pressure parameter prediction theory under different gas sources and temperature and pressure conditions, strong adaptability, and quick and simple calculation.

FIG. 3 is a schematic structural diagram of an apparatus for configuring operating parameters of a gas injection apparatus according to an embodiment of the present invention, the apparatus including:

the bottom-hole flowing pressure obtaining module 301 is configured to obtain a target bottom-hole flowing pressure based on a basic oil reservoir parameter, an injected gas parameter, a gas injection key design parameter, a gas phase viscosity calculation model and a bottom-hole flowing pressure calculation model of an oil well, where the basic oil reservoir parameter includes a formation temperature, an oil layer depth, an oil layer thickness and a permeability, the injected gas parameter includes a relative density of gas, an average compression factor of gas, an average relative molecular mass of gas and an injected gas wellhead temperature, and the gas injection key design parameter includes preset oil reservoir pressure, a well type, a daily gas injection amount on the ground, an inner diameter of an injection oil pipe and relative roughness.

A wellbore segmentation module 302 for dividing the well into a plurality of wellbore segments based on a preset step size.

A lower end pressure obtaining module 303, configured to sequentially obtain a lower end pressure of each wellbore section based on the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter, the target bottom hole flowing pressure, the gas phase viscosity calculation model, and the pressure difference calculation model of each wellbore section.

And the wellhead gas injection pressure acquisition module 304 is used for acquiring the upper end pressure of the uppermost wellbore section in the wellbore sections as the wellhead gas injection pressure of the oil well.

And a parameter configuration module 305, configured to configure operating parameters of the gas injection equipment based on the wellhead gas injection pressure.

And the gas injection module 306 is used for injecting gas into the oil well based on the configured gas injection equipment.

In one possible implementation, the apparatus further includes:

the oil reservoir pressure acquisition module is used for acquiring first oil reservoir pressure in the gas injection process.

The parameter configuration module 305 is further configured to adjust the operating parameter of the gas injection device to obtain a second reservoir pressure when the absolute value of the difference between the first reservoir pressure and the target reservoir pressure is not less than a first preset threshold, so that the absolute value of the difference between the second reservoir pressure and the target reservoir pressure is less than the first preset threshold.

and for any one preset first bottom hole flowing pressure, acquiring first gas phase viscosity based on the first bottom hole flowing pressure, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the gas phase viscosity calculation model.

And outputting a second bottom hole flowing pressure based on the first gas phase viscosity, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the bottom hole flowing pressure calculation model.

the formula I is as follows:

the second formula is as follows:

the formula III is as follows:

the formula IV is as follows:

is the average compressibility factor, dimensionless, K is the permeability in mD, h is the reservoir thickness in m, r _e Is the effective radius of the vertical well, and has the unit of m, r _w Is the radius of the oil interval borehole, and has the unit of m, s is a first skin coefficient, and has no dimension, DQ _sc Is the second skin coefficient, dimensionless, gamma _g For relative density of injected gas, dimensionless, T _sc Is standard temperature in K, K _h Is the vertical permeability in mD, P _sc Is standard atmospheric pressure in MPa, a is a first parameter, L is the length of the horizontal section in m, delta is a deviation coefficient, r is a dimensionless value _eh Is the effective radius of the horizontal well in m.

the gas phase viscosity is obtained based on the following formula five to formula ten:

the formula five is as follows:

formula six:

the formula seven:

the formula eight:

the formula is nine: y =2.4-0.2X

Formula ten:

is an average compression factor, dimensionless, M _g Mean relative molecular mass, dimensionless.

formula eleven:

equation twelve:

formula thirteen:

the formula fourteen:

Is the average formation temperature, in K,

d is the inner diameter of the injection oil pipe and has the unit of m, gamma _g Is the relative density of injected gas, and is dimensionless, delta H is a preset step length, the unit is m, g is the gravity acceleration, the unit is m/s ² Reynolds number at the lower end of the ith wellbore section of Re (i), dimensionless, γ _g In order to obtain the relative density of the injected gas, the gas is dimensionless,

It should be noted that: the above embodiments provide an operating parameter configuration apparatus for an insufflation apparatus, which is only illustrated by dividing the functional modules when configuring parameters of the insufflation apparatus, and in practical applications, the above functions can be allocated by different functional modules according to needs, that is, the internal structure of the apparatus can be divided into different functional modules to complete all or part of the above described functions. In addition, the working parameter configuration device of the gas injection apparatus provided in the above embodiment and the working parameter configuration method embodiment of the gas injection apparatus belong to the same concept, and specific implementation processes thereof are described in the method embodiment and are not described herein again.

According to the device provided by the embodiment of the invention, the wellhead gas injection pressure is obtained based on the preset bottom hole flowing pressure and various parameters of the oil well, the working parameters of the gas injection equipment are adjusted based on the wellhead gas injection pressure, and gas injection is carried out, so that the wellhead gas injection pressure meeting the requirement can be quickly and simply obtained, a test by using a gas injection compressor and related supporting equipment is avoided, a complex implementation process is also avoided, the working parameters of the gas injection equipment can be quickly configured, the efficiency of the gas injection process is improved, and the cost of the gas injection process is also reduced.

Fig. 4 is a schematic structural diagram of a computer device 400 according to an embodiment of the present invention, where the computer device 400 may generate a relatively large difference due to different configurations or performances, and may include one or more processors (CPUs) 401 and one or more memories 402, where the memory 402 stores at least one instruction, and the at least one instruction is loaded and executed by the processor 401 to implement the methods provided by the method embodiments. Certainly, the computer device may further have components such as a wired or wireless network interface, a keyboard, and an input/output interface, so as to perform input and output, and the computer device may further include other components for implementing the functions of the device, which is not described herein again.

In an exemplary embodiment, a computer-readable storage medium, such as a memory, is also provided that includes instructions executable by a processor in a computer device to perform the method for configuring operating parameters of an insufflation apparatus of the embodiments described above. For example, the computer readable storage medium may be a Read-Only Memory (ROM), a Random Access Memory (RAM), a Compact Disc Read-Only Memory (CD-ROM), a magnetic tape, a floppy disk, an optical data storage device, and the like.

It will be understood by those skilled in the art that all or part of the steps for implementing the above embodiments may be implemented by hardware, or may be implemented by a program instructing relevant hardware, where the program may be stored in a computer-readable storage medium, and the storage medium may be a read-only memory, a magnetic disk or an optical disk.

The above description is only exemplary of the present invention and should not be taken as limiting the invention, as any modification, equivalent replacement, or improvement made within the spirit and principle of the present invention should be included in the protection scope of the present invention.

Claims

1. A method of configuring operating parameters of a gas injection apparatus, the method comprising:

for any one preset first bottom hole flowing pressure, obtaining first gas phase viscosity based on the first bottom hole flowing pressure, basic oil reservoir parameters of an oil well, injected gas parameters, gas injection key design parameters and a gas phase viscosity calculation model;

outputting a second bottom hole flowing pressure based on the first gas phase viscosity, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and a bottom hole flowing pressure calculation model;

when the absolute value of the difference between the second bottom-hole flowing pressure and the preset bottom-hole flowing pressure is not smaller than a second preset threshold value, acquiring the second bottom-hole flowing pressure as the first bottom-hole flowing pressure, and performing iteration until the absolute value of the difference between the output bottom-hole flowing pressure and the preset bottom-hole flowing pressure is smaller than the second preset threshold value, acquiring the output bottom-hole flowing pressure as a target bottom-hole flowing pressure, wherein basic oil reservoir parameters comprise formation temperature, oil layer depth, oil layer thickness and permeability, the injected gas parameters comprise the relative density of gas, the average compression factor of gas, the average relative molecular mass of gas and the injection gas wellhead temperature, and the key design parameters of gas injection comprise preset oil reservoir pressure, well type, ground daily injection gas, injection oil pipe inner diameter and relative roughness;

the method comprises the following steps of using i to represent the number of wellbore sections, using N to represent the total number of wellbore sections, wherein i is less than or equal to N, N is an integer greater than or equal to 1, and for any two adjacent ith wellbore sections and (i + 1) th wellbore sections, obtaining the lower end pressure of the (i + 1) th wellbore section according to the lower end pressure of the ith wellbore section comprises the following steps:

acquiring gas phase viscosity of the lower end of the ith wellbore section based on the pressure of the lower end of the ith wellbore section, the basic reservoir parameter, the injected gas parameter, the gas injection key design parameter and the gas phase viscosity calculation model;

outputting a fourth lower end pressure of the (i + 1) th wellbore section based on the average gas phase viscosity of the ith wellbore section, the basic reservoir parameter, the injected gas parameter, the gas injection key design parameter and a differential pressure calculation model of the ith wellbore section;

when the absolute value of the difference between the fourth lower end pressure of the (i + 1) th wellbore section and the preset lower end pressure of the (i + 1) th wellbore section is not smaller than a third preset threshold, acquiring the fourth lower end pressure as the third lower end pressure, and performing iteration until the absolute value of the difference between the output lower end pressure and the preset lower end pressure is smaller than the third preset threshold, acquiring the output lower end pressure as the lower end pressure of the (i + 1) th wellbore section;

sequentially obtaining the lower end pressure of each wellbore section based on a method for obtaining the lower end pressure of the (i + 1) th wellbore section from the lower end pressure of the ith wellbore section, the basic reservoir parameter, the injected gas parameter, the gas injection key design parameter, the target bottom hole flowing pressure, the gas phase viscosity calculation model and the pressure difference calculation model of each wellbore section;

injecting gas into the oil well based on the configured gas injection equipment;

wherein the bottom hole flow pressure calculation model comprises:

obtaining the target bottom hole flowing pressure based on the following formulas I to IV:

the formula I is as follows:

the formula II is as follows:

the formula III is as follows:

the formula four is as follows:

wherein, P _wf Is the target bottom hole flowing pressure in MPa, P _e In order to preset reservoir pressure in MPa, Q _sc The daily gas injection amount on the ground is in Nm ³ D, T is the formation temperature in K,

is the average compressibility factor, dimensionless, K is permeability in mD, h is the oil layer thickness in m, r _e Is the effective radius of the vertical well, and has the unit of m, r _w Is the radius of the oil interval borehole, the unit is m, s is a first skin coefficient, dimensionless, DQ _sc Is the second skin coefficient, dimensionless, gamma _g For relative density of injected gas, dimensionless, T _sc Is standard temperature in K, K _h Is the vertical permeability in mD, P _sc Is a standard largeAir pressure in MPa, a is a first parameter, L is the length of the horizontal section in m, delta is a deviation coefficient, and r is dimensionless _eh Is the effective radius of the horizontal well in m.

2. The method of claim 1, further comprising:

acquiring a first reservoir pressure in a gas injection process;

and when the absolute value of the difference between the first reservoir pressure and the target reservoir pressure is not less than a first preset threshold value, adjusting the working parameters of the gas injection equipment to obtain a second reservoir pressure, so that the absolute value of the difference between the second reservoir pressure and the target reservoir pressure is less than the first preset threshold value.

3. The method of claim 1, wherein the gas phase viscosity calculation model comprises:

obtaining the gas phase viscosity based on the following formulas five to ten:

the formula five is as follows:

the formula six:

the formula seven:

the formula eight:

the formula is nine: y =2.4-0.2X

The formula ten:

wherein, mu _g (i) Is the gas phase viscosity at the lower end of the ith well barrel section, the unit is mPa.s, e is a natural constant, A, X and Y are intermediate parameters, rho _g (i) Is the gas density at the lower end of the ith wellbore section, and has the unit of g/cm ³ ，γ _g In order to obtain the relative density of injected gas, P (i) is the pressure of the lower end of the ith well cylinder section in MPa, T (i) is the temperature of the lower end of the ith well cylinder section in K,

4. The method of claim 1, wherein the differential pressure calculation model comprises:

formula eleven:

the formula twelve:

equation thirteen:

the formula fourteen is as follows:

Is the average formation temperature, in K,

d is the inner diameter of the injection oil pipe and has the unit of m, gamma _g Is the relative density of injected gas, and is dimensionless, delta H is a preset step length, the unit is m, g is the gravity acceleration, the unit is m/s ² Reynolds number at the lower end of the ith wellbore section of Re (i), dimensionless, γ _g The relative density of the injected gas is a dimensionless,

5. An apparatus for configuring operating parameters of a gas injection apparatus, the apparatus comprising:

the system comprises a bottom hole flowing pressure obtaining module, a gas phase viscosity calculating module and a gas phase viscosity calculating module, wherein the bottom hole flowing pressure obtaining module is used for obtaining first gas phase viscosity based on any preset first bottom hole flowing pressure, basic oil deposit parameters of an oil well, injected gas parameters, gas injection key design parameters and a gas phase viscosity calculating model;

when the absolute value of the difference between the second bottom-hole flowing pressure and the preset bottom-hole flowing pressure is not smaller than a second preset threshold value, acquiring the second bottom-hole flowing pressure as the first bottom-hole flowing pressure, and performing iteration until the absolute value of the difference between the output bottom-hole flowing pressure and the preset bottom-hole flowing pressure is smaller than the second preset threshold value, acquiring the output bottom-hole flowing pressure as the target bottom-hole flowing pressure, wherein the basic oil reservoir parameters comprise formation temperature, oil layer depth, oil layer thickness and permeability, the injected gas parameters comprise the relative density of gas, the average compression factor of gas, the average relative molecular mass of gas and the injection gas wellhead temperature, and the key design parameters of gas injection comprise preset oil reservoir pressure, well type, ground daily injection gas, injection oil pipe inner diameter and relative roughness;

the lower end pressure obtaining module is used for representing the number of the wellbore sections by i and the total number of the wellbore sections by N, wherein i is less than or equal to N, N is an integer greater than or equal to 1, and for any two adjacent ith wellbore sections and (i + 1) th wellbore sections, obtaining the lower end pressure of the (i + 1) th wellbore section by the lower end pressure of the ith wellbore section comprises the following steps:

acquiring gas phase viscosity of the lower end of the ith wellbore section based on the pressure of the lower end of the ith wellbore section, the basic oil reservoir parameter, the injected gas parameter, the gas injection key design parameter and the gas phase viscosity calculation model;

the parameter configuration module is used for configuring working parameters of gas injection equipment based on the wellhead gas injection pressure;

the gas injection module is used for injecting gas into the oil well based on the configured gas injection equipment;

wherein the bottom hole flow pressure calculation model comprises:

the formula I is as follows:

the second formula is as follows:

the formula III is as follows:

the formula four is as follows:

wherein, P _wf Is the target bottom hole flowing pressure in MPa, P _e In order to preset reservoir pressure, in MPa, Q _sc The daily gas injection amount on the ground is in Nm ³ D, T is the formation temperature in K,

is the average compressibility factor, dimensionless, K is permeability in mD, h is the oil layer thickness in m, r _e Is the effective radius of the vertical well, and has the unit of m, r _w Is the radius of the oil interval borehole, and has the unit of m, s is a first skin coefficient, and has no dimension, DQ _sc Is the second skin coefficient, dimensionless, gamma _g Relative density, dimensionless, T, of injected gas _sc Is standard temperature in K, K _h Is the vertical permeability in mD, P _sc Is standard atmospheric pressure in MPa, a is a first parameter, L is the length of the horizontal segment in m, delta is the deviation coefficient, and r is dimensionless _eh Is the effective radius of the horizontal well and is expressed in m.

6. The apparatus of claim 5, further comprising: