CN111255434A

CN111255434A - Well testing method and device for gas well and computer storage medium

Info

Publication number: CN111255434A
Application number: CN201811452621.8A
Authority: CN
Inventors: 邓惠; 彭先; 冯曦; 朱斌; 姚宏宇; 鲁杰; 杨泽恩; 张岩; 鄢友军; 朱讯
Original assignee: Petrochina Co Ltd
Current assignee: Petrochina Co Ltd
Priority date: 2018-11-30
Filing date: 2018-11-30
Publication date: 2020-06-09
Anticipated expiration: 2038-11-30
Also published as: CN111255434B

Abstract

The invention discloses a well testing method for a gas well, and belongs to the field of gas well exploitation. The method comprises the following steps: acquiring the oil testing yield and the wellhead oil pressure of a gas well in the well opening process of oil testing, and acquiring the wellhead oil pressure of the gas well in the well closing process of oil testing; determining the bottom hole flowing pressure of the gas well according to the wellhead oil pressure of the gas well in the well opening process of oil testing; determining the formation static pressure of the gas well according to the well head oil pressure of the gas well in the well closing process of oil testing; determining the yield range of the gas well according to the oil testing yield of the gas well in the oil testing well opening process, the bottom hole flowing pressure of the gas well and the formation static pressure; and testing the gas well according to the yield range of the gas well. According to the method, the yield range of the gas well is predicted by taking the data obtained in the oil testing process of the gas well as the basis, so that the well testing of the gas well can be carried out after the oil testing of the gas well is finished and before the gas well is put into production, and thus, the production time of the gas well does not need to be occupied in the well testing process of the gas well, and the normal production of the gas well cannot be influenced.

Description

Well testing method and device for gas well and computer storage medium

Technical Field

The invention relates to the field of gas well exploitation, in particular to a gas well testing method and device and a computer storage medium.

Background

In order to evaluate the productivity of a gas well, the gas well is often tested. Well testing is to determine the productivity of a gas well by measuring parameters such as the production and pressure of the gas well over a period of time and analyzing the parameters.

At present, a method for testing a gas well generally comprises a back pressure well testing method and an isochronous well testing method. The process of the back pressure well testing method comprises the following steps: the method comprises the steps of firstly determining the yield range of a tested well according to the yield of the gas well after production, then selecting a plurality of yields from the yield range, then stably producing the gas well with the plurality of yields respectively, recording data such as bottom hole flowing pressure and used time in the production process, drawing a well testing curve according to the recorded data, deducing a productivity equation of the gas well according to the well testing curve, and determining the productivity of the gas well according to the productivity equation. The process of the isochronous well testing method is as follows: the method comprises the steps of firstly determining the yield range of a tested well according to yield data of the gas well after production, then selecting a plurality of yields from the yield range, then respectively carrying out equal-duration production on the gas well according to the plurality of yields, then carrying out longer-duration stable production according to a smaller yield, recording bottom hole flowing pressure, used duration and other data in the whole production process, drawing a well testing curve according to the recorded data, deducing a productivity equation of the gas well according to the well testing curve, and determining the productivity of the gas well according to the productivity equation.

However, in the well testing methods, the production range of the well testing needs to be determined according to the production of the gas well after the gas well is put into production, so the well testing methods need to be executed after the gas well is put into production, and the time required by the well testing process is often long, so the normal production of the gas well is greatly influenced.

Disclosure of Invention

The embodiment of the invention provides a well testing method and device for a gas well and a computer storage medium, which can solve the problem that the well testing method in the related art can be executed only after the gas well is put into production. The technical scheme is as follows:

in a first aspect, a well testing method for a gas well is provided, the method comprising:

acquiring the oil testing yield and the wellhead oil pressure of a gas well in the well opening process of oil testing, and acquiring the wellhead oil pressure of the gas well in the well closing process of oil testing;

determining the bottom hole flowing pressure of the gas well according to the wellhead oil pressure of the gas well in the well opening process of oil testing;

determining the formation static pressure of the gas well according to the wellhead oil pressure of the gas well in the well closing process of oil testing;

determining the yield range of the gas well according to the oil testing yield of the gas well in the oil testing well opening process, the bottom hole flowing pressure and the stratum static pressure of the gas well;

and testing the gas well according to the yield range of the gas well.

Optionally, the determining the bottom hole flowing pressure of the gas well according to the wellhead oil pressure of the gas well in the well opening process of oil testing comprises:

acquiring the distance between the wellhead of the gas well and a gas layer where the gas well is located;

multiplying the distance between the wellhead and the gas layer by a preset flowing pressure gradient to obtain a first pressure increment;

and adding the stable value of the wellhead oil pressure of the gas well in the well opening process of oil testing and the first pressure increment to obtain the bottom hole flowing pressure of the gas well.

Optionally, the determining the formation static pressure of the gas well according to the wellhead oil pressure of the gas well in the well shut-in process of oil testing comprises:

multiplying the distance between the wellhead and the gas layer by a preset static pressure gradient to obtain a second pressure increment;

and adding the maximum value of the wellhead oil pressure of the gas well in the well closing process of oil testing and the second pressure increment to obtain the formation static pressure of the gas well.

Optionally, the determining the production range of the gas well according to the oil testing production of the gas well in the oil testing well opening process, the bottom hole flowing pressure of the gas well and the formation static pressure comprises:

determining a first unobstructed flow of the gas well according to the oil testing yield of the gas well in the oil testing well opening process, the bottom hole flowing pressure of the gas well and the formation static pressure;

multiplying the first choked flow quantity of the gas well by a first proportion to obtain a first numerical value; multiplying the first choked flow quantity of the gas well by a second proportion to obtain a second numerical value, wherein the second proportion is larger than the first proportion;

determining a production range having a minimum value of the first number and a maximum value of the second number as a production range of the gas well.

Optionally, the well testing of the gas well according to the production range of the gas well includes:

selecting a production from the production range of the gas well as a first production;

carrying out open-hole production on the gas well within a first preset time length at the first yield, and recording the bottom hole flowing pressure of the gas well within the first preset time length in the open-hole production process;

closing the gas well within a second preset time period, and recording the bottom hole flowing pressure of the gas well within the second preset time period in the well closing process;

acquiring logging data of the gas well;

acquiring a well testing model of the gas well and reservoir parameters of a gas layer where the gas well is located according to the bottom hole flowing pressure of the gas well in the first preset time length, the bottom hole flowing pressure of the gas well in the second preset time length and the logging data of the gas well;

and determining a second unobstructed flow of the gas well according to the production range of the gas well, the well testing model and the reservoir parameters.

Optionally, the determining a second unobstructed flow rate of the gas well according to the production range of the gas well, the well testing model and the reservoir parameters includes:

selecting n yields from the yield range of the gas well as n second yields, wherein n is an integer greater than or equal to 2;

determining a turbulence coefficient in a binomial productivity equation according to the n second yields and the formation static pressure included in the reservoir parameters;

acquiring a minimum yield and a maximum yield of the n second yields;

determining a yield range with the minimum value as the minimum yield and the maximum value as the maximum yield as a target yield range;

selecting one yield from the target yield range as a third yield;

determining a laminar flow coefficient in the binomial productivity equation according to the third yield, the well testing model, the turbulence coefficient and the formation static pressure included in the reservoir parameters;

and determining a second unobstructed flow of the gas well through the binomial productivity equation according to the turbulence coefficient, the laminar flow coefficient and the formation static pressure included in the reservoir parameters.

Optionally, the determining a turbulence factor in a binomial productivity equation according to the n second productions and the static formation pressure included in the reservoir parameters comprises:

taking an ith second yield of the n second yields as a target yield, wherein i is greater than or equal to 1 and less than or equal to n;

carrying out ith well opening production on the gas well within a third preset time length according to the target yield, and when i is not 1, determining the instant bottom hole flow pressure from the i-1 th well opening production to the ith well opening production as a first bottom hole flow pressure corresponding to the i-1 th second yield;

when the ith well opening production is finished, judging whether i is equal to n or not; if i is equal to n, determining the instant bottom hole flow pressure when the ith well-opening production is finished as a first bottom hole flow pressure corresponding to the ith second production; if i is not equal to n, making i equal to i +1, and returning to the step of taking the ith yield of the n second yields as a target yield;

determining n coordinate points in one-to-one correspondence with the n second yields according to the n second yields, the first bottom hole flowing pressure corresponding to each second yield in the n second yields and the static formation pressure included in the reservoir parameters;

performing curve fitting on the n coordinate points to obtain a first curve;

and determining the slope of the first curve as the turbulence coefficient in the binomial capacity equation.

Optionally, the determining n coordinate points corresponding to the n second productions in a one-to-one manner according to the n second productions, the first bottom hole flow pressure corresponding to each of the n second productions, and the static formation pressure included in the reservoir parameter includes:

determining an ith second yield of the n second yields as an abscissa of a coordinate point corresponding to the ith second yield;

and subtracting the square of the first bottom hole flowing pressure corresponding to the ith second yield from the square of the static pressure of the stratum included in the reservoir parameters, and dividing the square of the first bottom hole flowing pressure corresponding to the ith second yield by the ith second yield to obtain the ordinate of the coordinate point corresponding to the ith second yield.

Optionally, the determining the laminar flow coefficient in the binomial productivity equation according to the third production, the well test model, the turbulence coefficient, and the static formation pressure included in the reservoir parameters includes:

inputting the third yield into the well testing model, simulating the well opening production of the gas well in a fourth preset time period by using the well testing model, and outputting the simulated bottom hole flowing pressure of the gas well in the fourth preset time period;

determining a target coordinate point according to the third yield, the simulated bottom hole flowing pressure output by the well testing model and the stratum static pressure included in the reservoir parameters;

determining a curve which passes through the target coordinate point and has a slope of the turbulence coefficient as a second curve;

and determining the intercept of the second curve on the horizontal axis as the laminar flow coefficient in the binomial capacity equation.

In a second aspect, there is provided a well testing apparatus for a gas well, the apparatus comprising:

the acquisition module is used for acquiring the oil testing yield and the wellhead oil pressure of the gas well in the well opening process of oil testing and acquiring the wellhead oil pressure of the gas well in the well closing process of oil testing;

the first determination module is used for determining the bottom hole flowing pressure of the gas well according to the wellhead oil pressure of the gas well in the well opening process of oil testing;

the second determination module is used for determining the formation static pressure of the gas well according to the wellhead oil pressure of the gas well in the well closing process of oil testing;

the third determination module is used for determining the yield range of the gas well according to the oil testing yield of the gas well in the well opening process of oil testing, the bottom hole flowing pressure of the gas well and the formation static pressure;

and the well testing module is used for testing the gas well according to the yield range of the gas well.

Optionally, the first determining module includes:

the first acquisition unit is used for acquiring the distance between the wellhead of the gas well and a gas layer where the gas well is located;

the first calculation unit is used for multiplying the distance between the wellhead and the gas layer by a preset flow pressure gradient to obtain a first pressure increment;

and the second calculation unit is used for adding the stable value of the wellhead oil pressure of the gas well in the well opening process of oil testing and the first pressure increment to obtain the bottom hole flowing pressure of the gas well.

Optionally, the second determining module includes:

the second acquisition unit is used for acquiring the distance between the wellhead of the gas well and a gas layer where the gas well is located;

the third calculation unit is used for multiplying the distance between the wellhead and the gas layer by a preset static pressure gradient to obtain a second pressure increment;

and the fourth calculation unit is used for adding the maximum value of the wellhead oil pressure of the gas well in the well closing process of oil testing and the second pressure increment to obtain the formation static pressure of the gas well.

Optionally, the third determining module includes:

the first determination unit is used for determining a first unobstructed flow of the gas well according to the oil testing yield of the gas well in the oil testing well opening process, the bottom hole flow pressure of the gas well and the formation static pressure;

the fourth calculation unit is used for multiplying the first chokeless flow quantity of the gas well by the first proportion to obtain a first numerical value; multiplying the first choked flow quantity of the gas well by a second proportion to obtain a second numerical value, wherein the second proportion is larger than the first proportion;

and the second determining unit is used for determining the production range with the minimum value as the first value and the maximum value as the second value as the production range of the gas well.

Optionally, the well testing module comprises:

a selection unit for selecting one production from the production range of the gas well as a first production;

the first recording unit is used for carrying out open-hole production on the gas well within a first preset time length in the first yield, and recording the bottom hole flowing pressure of the gas well within the first preset time length in the open-hole production process;

the second recording unit is used for closing the gas well within a second preset time period and recording the bottom hole flowing pressure of the gas well within the second preset time period in the well closing process;

the third acquisition unit is used for acquiring logging data of the gas well;

the fourth obtaining unit is used for obtaining a well testing model of the gas well and reservoir parameters of a gas layer where the gas well is located according to the bottom hole flowing pressure of the gas well in the first preset time length, the bottom hole flowing pressure of the gas well in the second preset time length and the logging data of the gas well;

and the third determining unit is used for determining a second unobstructed flow of the gas well according to the production range of the gas well, the well testing model and the reservoir parameters.

Optionally, the third determining unit includes:

a first selection subunit, configured to select n yields from a yield range of the gas well as n second yields, where n is an integer greater than or equal to 2;

a first determining subunit, configured to determine a turbulence coefficient in a binomial productivity equation according to the n second productions and a formation static pressure included in the reservoir parameter;

an obtaining subunit, configured to obtain a minimum yield and a maximum yield of the n second yields;

a second determining subunit, configured to determine a yield range with a minimum value as the minimum yield and a maximum value as the maximum yield as a target yield range;

a second selecting subunit that selects one yield from the target yield range as a third yield;

a third determining subunit, configured to determine a laminar flow coefficient in the binomial productivity equation according to the third yield, the well test model, the turbulence coefficient, and a formation static pressure included in the reservoir parameter;

and the fourth determining subunit is used for determining a second unobstructed flow of the gas well through the binomial productivity equation according to the turbulence coefficient, the laminar flow coefficient and the formation static pressure included in the reservoir parameters.

Optionally, the first determining subunit is configured to:

performing curve fitting on the n coordinate points to obtain a first curve;

Optionally, the first determining subunit is configured to:

Optionally, the third determining subunit is configured to:

In a third aspect, a well testing device for a gas well is provided, where the device includes a processor, a memory, and a program code stored in the memory and executable on the processor, and when the processor executes the program code, the well testing method for the gas well according to the first aspect is implemented.

In a fourth aspect, a computer-readable storage medium is provided, the storage medium having stored thereon instructions that, when executed by a processor, perform the steps of the method for testing a gas well of the first aspect.

The technical scheme provided by the embodiment of the invention can at least bring the following beneficial effects:

in the embodiment of the invention, the oil testing yield and the wellhead oil pressure of the gas well in the oil testing well opening process are firstly obtained, the wellhead oil pressure of the gas well in the oil testing well closing process is obtained, the bottom hole flowing pressure of the gas well is determined according to the wellhead oil pressure of the gas well in the oil testing well opening process, and then the formation static pressure of the gas well is determined according to the wellhead oil pressure of the gas well in the oil testing well closing process. And finally, testing the gas well according to the yield of the gas well in the well testing and opening process, the bottom hole flowing pressure and the stratum static pressure of the gas well. According to the embodiment of the invention, the yield range of the gas well is predicted by taking the data obtained in the oil testing process of the gas well as a basis, so that the well testing of the gas well can be carried out after the oil testing of the gas well is finished and before the gas well is put into production, and thus, the production time of the gas well does not need to be occupied in the well testing process of the gas well, and the normal production of the gas well cannot be influenced.

Drawings

In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the drawings needed to be used in the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.

FIG. 1 is a flow chart of a well testing method for a gas well provided by an embodiment of the present invention;

FIG. 2 is a flow chart of a method of testing another gas well provided by an embodiment of the present invention;

FIG. 3 is a flow chart of an operation for determining a second unobstructed flow rate for a gas well provided by an embodiment of the present invention;

FIG. 4 is a schematic diagram of a well testing apparatus for a gas well according to an embodiment of the present invention;

fig. 5 is a schematic structural diagram of a well testing device for another gas well according to an embodiment of the present invention.

Detailed Description

In order 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 well testing method for a gas well according to an embodiment of the present invention. Referring to fig. 1, the method includes:

step 101: the method comprises the steps of obtaining the oil testing yield and the wellhead oil pressure of the gas well in the well opening process of oil testing, and obtaining the wellhead oil pressure of the gas well in the well closing process of oil testing.

Step 102: and determining the bottom hole flowing pressure of the gas well according to the wellhead oil pressure of the gas well in the well opening process of oil testing.

Step 103: and determining the formation static pressure of the gas well according to the well head oil pressure of the gas well in the well closing process of oil testing.

Step 104: and determining the yield range of the gas well according to the oil testing yield of the gas well in the oil testing well opening process, the bottom hole flowing pressure of the gas well and the formation static pressure.

Step 105: and testing the gas well according to the yield range of the gas well.

Optionally, determining the bottom hole flowing pressure of the gas well according to the wellhead oil pressure of the gas well in the well opening process of oil testing, wherein the determining comprises:

acquiring the distance between a wellhead of a gas well and a gas layer where the gas well is located;

multiplying the distance between the wellhead and the gas layer by a preset flow pressure gradient to obtain a first pressure increment;

Optionally, determining the formation static pressure of the gas well according to the wellhead oil pressure of the gas well in the well shut-in process of oil testing comprises:

Optionally, determining a production range of the gas well according to the oil testing yield of the gas well in the well opening process of oil testing, the bottom hole flowing pressure of the gas well and the static formation pressure, wherein the production range of the gas well comprises:

and determining the production range with the minimum value as the first value and the maximum value as the second value as the production range of the gas well.

Optionally, the well testing is performed on the gas well according to the production range of the gas well, and comprises:

selecting a production from a range of production for a gas well as a first production;

carrying out open-hole production on the gas well within a first preset time length at a first yield, and recording the bottom hole flowing pressure of the gas well within the first preset time length in the open-hole production process;

closing the gas well within a second preset time, and recording the bottom hole flowing pressure of the gas well within the second preset time in the well closing process;

acquiring logging data of a gas well;

acquiring a well testing model of the gas well and reservoir parameters of a gas layer where the gas well is located according to the bottom hole flowing pressure of the gas well in a first preset time period, the bottom hole flowing pressure of the gas well in a second preset time period and logging data of the gas well;

and determining the second unobstructed flow of the gas well according to the yield range, the well testing model and the reservoir parameters of the gas well.

Optionally, determining a second unobstructed flow rate of the gas well according to the production range, the well testing model and the reservoir parameters of the gas well, including:

acquiring the minimum yield and the maximum yield of the n second yields;

selecting one yield from the target yield range as a third yield;

determining a laminar flow coefficient in a binomial productivity equation according to the third yield, the well test model, the turbulence coefficient and the formation static pressure included in the reservoir parameters;

and determining the second unobstructed flow of the gas well through a binomial productivity equation according to the turbulence coefficient, the laminar flow coefficient and the formation static pressure included in the reservoir parameters.

Optionally, determining the turbulence factor in the binomial productivity equation based on the n second productions and the static formation pressure included in the reservoir parameters comprises:

taking the ith second yield of the n second yields as a target yield, wherein i is greater than or equal to 1 and less than or equal to n;

carrying out ith well opening production on the gas well within a third preset time length according to the target yield, and when i is not 1, determining the instantaneous bottom hole flow pressure from the i-1 th well opening production to the ith well opening production as a first bottom hole flow pressure corresponding to the i-1 th second yield;

when the ith well opening production is finished, judging whether i is equal to n; if i is equal to n, determining the instant bottom hole flow pressure when the ith well-opening production is finished as a first bottom hole flow pressure corresponding to the ith second production; if i is not equal to n, making i equal to i +1, and returning to the step of taking the ith yield of the n second yields as the target yield;

performing curve fitting on the n coordinate points to obtain a first curve;

the slope of the first curve is determined as the turbulence factor in the binomial energy production equation.

Optionally, determining n coordinate points corresponding to the n second productions one-to-one according to the n second productions, the first bottom hole flow pressure corresponding to each of the n second productions, and the formation static pressure included in the reservoir parameters, includes:

determining the ith second yield of the n second yields as an abscissa of a coordinate point corresponding to the ith second yield;

Optionally, determining the laminar flow coefficient in the binomial productivity equation according to the third production, the well test model, the turbulence coefficient and the formation static pressure included in the reservoir parameters comprises:

inputting the third yield into a well testing model, simulating the well opening production of the gas well in the fourth preset time length by using the well testing model, and outputting the simulated bottom hole flowing pressure of the gas well in the fourth preset time length;

determining a curve which passes through the target coordinate point and has a slope of a turbulence coefficient as a second curve;

All the above optional technical solutions can be combined arbitrarily to form an optional embodiment of the present invention, which is not described in detail herein.

Fig. 2 is a flowchart of a well testing method for a gas well according to an embodiment of the present invention. Referring to fig. 2, the method includes:

step 201: the method comprises the steps of obtaining the oil testing yield and the wellhead oil pressure of the gas well in the well opening process of oil testing, and obtaining the wellhead oil pressure of the gas well in the well closing process of oil testing.

Gas wells are wells drilled from the surface to the gas layer for the purpose of producing natural gas. The oil testing is to measure the pressure, temperature and other parameters in the gas well and detect the properties of the gas and oil in the gas well to recognize and identify the gas storage layer.

In addition, the production test yield is the yield of the gas well obtained in the well opening process when the gas well is tested, and the production test yield may be an average value of the yields of the gas well obtained in the well opening process of the oil test.

Again, wellhead oil pressure is the residual pressure of the natural gas after it has risen from the bottom of the gas well to the wellhead of the gas well.

Step 202: and determining the bottom hole flowing pressure of the gas well according to the wellhead oil pressure of the gas well in the well opening process of oil testing.

It should be noted that the bottom hole flow pressure is the residual pressure of the natural gas after flowing from the gas formation to the bottom of the gas well.

Specifically, the operation of step 202 may include steps 2021-2023 as follows:

step 2021: and acquiring the distance between the wellhead of the gas well and the gas layer where the gas well is located.

It should be noted that the gas layer is a stratum in which natural gas is stored, and because the gas layer has a certain thickness, and the middle part of the gas layer is a position where natural gas storage is mainly and intensively distributed, and also a position where the bottom hole flowing pressure of the gas well can be relatively accurately indicated, when the distance between the wellhead of the gas well and the gas layer where the gas well is located is obtained, the distance between the wellhead of the gas well and the middle part of the gas layer where the gas well is located can be obtained, so that relatively accurate bottom hole flowing pressure of the gas well can be obtained in the following process.

Step 2022: and multiplying the distance between the wellhead and the gas layer by a preset flow pressure gradient to obtain a first pressure increment.

It should be noted that the preset flowing pressure gradient can be preset to indicate the flowing pressure value which is increased in the unit depth of the distance from the wellhead to the stratum in the gas well. In order to obtain the preset flow pressure gradient relatively quickly, the flow pressure gradient of the adjacent gas well can be used as the preset flow pressure gradient.

Step 2023: and adding the stable value of the wellhead oil pressure of the gas well in the well opening process of oil testing and the first pressure increment to obtain the bottom hole flowing pressure of the gas well.

It should be noted that, when a gas well is just opened, the wellhead oil pressure is in an unstable state, the fluctuation range of the wellhead oil pressure is large, and the unstable wellhead oil pressure cannot accurately indicate the bottom hole flowing pressure of the gas well, so that the stable value of the wellhead oil pressure of the gas well when the wellhead oil pressure is stable in the opening process of oil testing is added to the first pressure increment to obtain the bottom hole flowing pressure of the gas well, so as to ensure the accuracy of the determined bottom hole flowing pressure of the gas well.

Step 203: and determining the formation static pressure of the gas well according to the well head oil pressure of the gas well in the well closing process of oil testing.

The formation static pressure is the static gas column pressure at which the gas formation is communicated with the earth surface, and generally, when the pressure in the gas well is recovered to a stable state after the well is shut down, the pressure in the middle of the gas formation is used as the formation static pressure.

Specifically, the operation of step 203 may include steps 2031 to 2033 as follows:

step 2031: and acquiring the distance between the wellhead of the gas well and the gas layer where the gas well is located.

It should be noted that the operation of step 2031 is similar to that of step 2021, and details thereof are not described again in this embodiment of the present invention.

Step 2032: and multiplying the distance between the wellhead and the gas layer by a preset static pressure gradient to obtain a second pressure increment.

It should be noted that the predetermined static pressure gradient may be predetermined to indicate a static pressure value in the gas well that increases per unit depth from the wellhead to the formation. In order to obtain the preset static pressure gradient relatively quickly, the static pressure gradient of the adjacent gas well can be used as the preset static pressure gradient.

Step 2033: and adding the maximum value of the wellhead oil pressure of the gas well in the well closing process of oil testing and the second pressure increment to obtain the formation static pressure of the gas well.

It should be noted that, because the formation static pressure is the pressure in the middle of the gas formation when the pressure in the gas well returns to a steady state after the gas well is shut in. And the pressure in the gas well can be recovered to a stable state after the gas well is shut down for a long time, and the time of the gas well in the well shut-down process of oil testing is usually shorter than the time of the gas well in the steady state, so that the maximum value of the wellhead oil pressure of the gas well in the well shut-down process of oil testing is added to the second pressure increment to obtain the formation static pressure of the gas well, so as to ensure the accuracy of the determined formation static pressure of the gas well.

Step 204: and determining the yield range of the gas well according to the oil testing yield of the gas well in the oil testing well opening process, the bottom hole flowing pressure of the gas well and the formation static pressure.

It is noted that the production range of a gas well is a range that indicates the minimum to maximum production of natural gas that the gas well can produce.

The method for testing the gas well comprises the steps of determining the yield range of the gas well according to the oil testing yield of the gas well in the oil testing well opening process, the bottom hole flowing pressure of the gas well and the stratum static pressure, and fully further excavating and using data obtained in the oil testing process of the gas well, so that the method for testing the gas well provided by the embodiment of the invention can be carried out after the oil testing of the gas well is finished and before the gas well is put into production, and under the condition, the well testing process of the gas well does not need to occupy the production time of the gas well, and the normal production of the gas well cannot be influenced.

Specifically, the operation of step 204 may include the following steps 2041 to 2043:

step 2041: and determining the first unobstructed flow of the gas well according to the oil testing yield of the gas well in the oil testing well opening process, the bottom hole flowing pressure of the gas well and the formation static pressure.

It should be noted that the first unobstructed flow rate is the maximum theoretical production of the gas well determined according to the production test of the gas well during the production test, the bottom hole flow pressure of the gas well and the static formation pressure. Because the gas well is not put into production during the oil testing period, the first unobstructed flow determined according to the oil testing yield of the gas well in the well opening process of the oil testing, the bottom hole flow pressure of the gas well and the formation static pressure is the estimated unobstructed flow and can be used for predicting the yield range of the gas well subsequently.

Specifically, the first unobstructed flow rate of the gas well can be determined according to the oil testing yield of the gas well in the oil testing well opening process, the bottom hole flow pressure of the gas well and the formation static pressure by the following formula:

wherein q is_AOFThe first unimpeded flow rate is in units of 10⁴m³/d(10⁴Cubic meters per day); q. q.s_gFor the yield, the unit is 10⁴m³/d(10⁴Cubic meters per day); p_RStatic formation pressure in MPa (megapascals); p_wfThe bottom hole flow pressure is in MPa.

Step 2042: multiplying the first choked flow quantity of the gas well by a first proportion to obtain a first numerical value; and multiplying the first choked flow quantity of the gas well by a second proportion to obtain a second numerical value, wherein the second proportion is larger than the first proportion.

It should be noted that the first ratio and the second ratio may be preset, and this is not particularly limited in the embodiment of the present invention. For example, the first ratio may be 10% or the like, and the second ratio may be 50% or the like.

Step 2043: and determining the production range with the minimum value as the first value and the maximum value as the second value as the production range of the gas well.

Step 205: and testing the gas well according to the yield range of the gas well.

It should be noted that well testing is to determine the productivity of a gas well by measuring parameters such as the production and pressure of the gas well over a period of time and analyzing the parameters.

It should be noted that, because the gas formation where the gas well is located is fractured and acidized to increase the gas production channel during oil testing, and the acid used therein may affect the well testing of the gas well, before step 205, the gas well may be subjected to blowout and drainage, that is, the gas well is first opened to discharge the acid in the gas well to the ground, and after the acid is discharged, the gas well is closed to stabilize the pressure in the gas well, and then step 205 is performed.

Specifically, the operation of step 205 may include the following steps 2051-2056:

step 2051: a production is selected from a range of production for the gas well as the first production.

It is noted that the first production may be a randomly selected one of a range of production from a gas well.

Step 2052: and carrying out open-hole production on the gas well within a first preset time period at a first yield, and recording the bottom hole flowing pressure of the gas well within the first preset time period in the open-hole production process.

It should be noted that the first preset time period may be preset, and this is not specifically limited in the embodiment of the present invention. For example, the first preset time period may be 10 hours, 12 hours, and the like.

In addition, the recording of the bottom hole flowing pressure of the gas well within the first preset duration in the well opening production process can be completed through a testing instrument which is arranged at the bottom of the gas well in advance, the testing instrument can transmit the recorded data such as the bottom hole flowing pressure to a terminal which is located on the ground in an optical fiber mode and the like, and the data such as the bottom hole flowing pressure and the like recorded by the testing instrument can be directly obtained from the terminal.

It is worth noting that a testing instrument used for recording data such as pressure, temperature and the like of a gas layer where a gas well is located is usually arranged at the bottom of the gas well before oil testing of the gas well, and the well testing process of the gas well in the embodiment of the invention can be directly carried out after the oil testing is finished.

Step 2053: and closing the gas well within a second preset time period, and recording the bottom hole flowing pressure of the gas well within the second preset time period in the well closing process.

It should be noted that the second preset time period may be preset, and since the gas well needs a longer time for the bottom hole flow pressure to reach the stable state after the well is shut down, the second preset time period may be longer, for example, the second preset time period may be 5 days, 6 days, and the like.

In addition, the operation of recording the bottom-hole flowing pressure of the gas well within the second preset time duration in the well closing process is similar to the operation of recording the bottom-hole flowing pressure of the gas well within the first preset time duration in the well opening production process, and details are not repeated for the embodiment of the invention.

Step 2054: and acquiring logging data of the gas well.

It should be noted that logging is a method for measuring formation parameters after drilling to a designed well depth when a gas well is drilled, and logging data may include effective thickness, porosity, gas saturation, and the like of a gas formation.

Step 2055: and acquiring a well testing model of the gas well and reservoir parameters of a gas layer where the gas well is located according to the bottom flowing pressure of the gas well in the first preset time period, the bottom flowing pressure of the gas well in the second preset time period and the logging data of the gas well.

The well testing model of the gas well is a mathematical model for describing the gas layer dynamic of the gas well in the well testing process, and can simulate the well opening production process of the gas well at a yield in a period of time and obtain the bottom hole flowing pressure of the gas well in the period of time.

In addition, the reservoir parameters are parameters for evaluating the properties of the gas reservoir. Reservoir parameters may include formation hydrostatic pressure, skin coefficient, permeability, and productivity coefficient, among others.

Specifically, the bottom hole flowing pressure of the gas well within the first preset time period, the bottom hole flowing pressure of the gas well within the second preset time period and the logging data of the gas well can be input into preset logging software, and the preset logging software outputs a logging model of the gas well and reservoir parameters of a gas layer where the gas well is located.

It should be noted that the preset well testing software may be preset, and this is not specifically limited in the embodiment of the present invention. For example, the pre-set well testing software may be PanSystem software, Saphir software, etc.

Step 2056: and determining the second unobstructed flow of the gas well according to the yield range, the well testing model and the reservoir parameters of the gas well.

It should be noted that the second unobstructed flow rate is the maximum theoretical production of the gas well determined according to the production range of the gas well, the well test model and the reservoir parameters. The second unobstructed flow rate may be used to assess the productivity of the gas well.

The operation of step 2056 may include the following steps (1) to (7):

(1) and selecting n yields from the yield range of the gas well as n second yields, wherein n is an integer greater than or equal to 2.

It should be noted that the n second yields may be n yields randomly selected from a range of yields of the gas well, and a difference between two adjacent second yields of the n second yields may be equal.

(2) And determining the turbulence factor in the binomial productivity equation according to the n second yields and the static pressure of the stratum included in the reservoir parameters.

It should be noted that the binomial capacity equation is an equation for calculating the capacity of the gas well, and the binomial capacity equation may be:

wherein q is_gFor the yield, the unit is 10⁴m³/d；P_RIs the formation static pressure in MPa; p_wfIs the bottom hole flowing pressure in MPa; a is a laminar flow coefficient; b is the turbulence factor.

In addition, the laminar flow coefficient is a characteristic coefficient which represents the complementary doping and orderly flow of natural gas micro-clusters in the gas well. The turbulence factor is a characteristic factor that represents the flow of a natural gas jet in a gas well.

Specifically, the operation of step (2) may include the following steps a to F:

step A: and taking the ith second yield of the n second yields as a target yield, wherein i is greater than or equal to 1 and less than or equal to n.

And B: and performing ith well opening production on the gas well within a third preset time length by using the target yield, and determining the instantaneous bottom hole flow pressure from the ith-1 well opening production to the ith well opening production as a first bottom hole flow pressure corresponding to the ith-1 second yield when i is not 1.

It should be noted that the third preset time period may be preset, and the third preset time period may be set to be shorter. For example, the third preset time period may be 3 hours, 5 hours, or the like.

It should be noted that, when the well testing process in the embodiment of the present invention is performed after the well testing of the gas well is completed and before the gas well is put into production, a complete pipeline device for transporting natural gas is not installed at the wellhead of the gas well, toxic and corrosive gases such as hydrogen sulfide contained in the gas well are liable to corrode a testing instrument arranged at the bottom of the gas well, and when the gas enters the air on the ground through the wellhead, the gas is liable to damage organisms around the gas well, so that the third preset time period can be set to be shorter to reduce unnecessary loss or damage.

And C: when the ith well opening production is finished, judging whether i is equal to n; if i is equal to n, determining the instant bottom hole flow pressure when the ith well-opening production is finished as a first bottom hole flow pressure corresponding to the ith second production; and if i is not equal to n, making i equal to i +1, and returning to the step A.

For example, 4 yields from the production range of a gas well are selected as 4 second yields, the 4 second yields being 15 × 10, respectively⁴m³/d、20×10⁴m³/d、25×10⁴m³D and 30X 10⁴m³D, mixing 15X 10⁴m³D as the first and second yields, 20X 10⁴m³D as second yield, 25X 10⁴m³D as third second yield, 30X 10⁴m³And/d as the fourth second yield. Then, the third preset time period is set to be 3 hours, and the gas well is set to be 15 multiplied by 10⁴m³First production of 3 hoursWhen the once well-opening production is completed, the gas well is directly divided into 20 multiplied by 10⁴m³D continuing the second production for 3 hours, and recording the instantaneous bottom hole flow pressure from the first production to the second production as 15 x 10⁴m³A first bottom hole flow pressure corresponding to/d; then when the second production is finished, the gas well is directly put at 25 multiplied by 10⁴m³D continuing the third production for 3 hours, and recording the instantaneous bottom hole flow pressure from the second production to the third production as 25X 10⁴m³The first bottom hole flow pressure corresponding to the/d is analogized until the fourth well-opening production is finished, and the instantaneous bottom hole flow pressure when the fourth well-opening production is finished is taken as 30 multiplied by 10⁴m³A first bottom hole flow pressure corresponding to/d. In this way, a first bottom hole flow pressure is obtained for each of the 4 second production volumes.

It is worth explaining, in the embodiment of the present invention, only n yields are selected from the yield range of the gas well as n second yields, and then the gas well is subjected to uninterrupted open-hole production for a third preset time duration with each of the n second yields, so that the first bottom-hole flow pressure corresponding to each of the n second yields can be obtained, so that the process of determining the turbulence coefficient in the binomial productivity equation is more time-saving and faster, and the well testing period of the gas well is shortened.

Step D: and determining n coordinate points in one-to-one correspondence with the n second yields according to the n second yields, the first bottom hole flowing pressure corresponding to each of the n second yields and the static formation pressure included in the reservoir parameters.

The coordinate point is a point having an abscissa and an ordinate in a two-dimensional coordinate system.

Specifically, the operation of step D may include the following steps a-b:

step a: and determining the ith second yield in the n second yields as the abscissa of the coordinate point corresponding to the ith second yield.

Step b: and subtracting the square of the first bottom hole flowing pressure corresponding to the ith second yield from the square of the static pressure of the stratum included in the reservoir parameters, and dividing the square of the first bottom hole flowing pressure corresponding to the ith second yield by the ith second yield to obtain the ordinate of the coordinate point corresponding to the ith second yield.

It should be noted that, after the abscissa and the ordinate of the coordinate point corresponding to the ith second yield are determined, the coordinate point corresponding to the ith second yield is determined.

Step E: and performing curve fitting on the n coordinate points to obtain a first curve.

It should be noted that, the operation of curve fitting the n coordinate points may refer to related technologies, which are not described in detail in the embodiments of the present invention.

Step F: the slope of the first curve is determined as the turbulence factor in the binomial energy production equation.

It should be noted that when the binomial capacity equation is

Then the equation may become

Q is to be_gAs the abscissa, the axis of the coordinate,

as an ordinate, a straight line can be obtained, the slope of which is B, and since B is expressed as the turbulence factor, the slope of the first curve can be determined as the turbulence factor in the binomial capacity equation.

(3) The minimum yield and the maximum yield of the n second yields are obtained.

(4) The yield range with the minimum value as the minimum yield and the maximum value as the maximum yield is determined as the target yield range.

It is noted that the target production range is included in the production range of the gas well.

(5) One yield is selected from the target yield range as a third yield.

The third yield may be a yield randomly selected from the target yield range, or may be the same as one of the n second yields.

(6) And determining the laminar flow coefficient in the binomial productivity equation according to the third yield, the well test model, the turbulence coefficient and the formation static pressure included in the reservoir parameters.

Wherein, the operation of step (6) may include steps (61) to (64):

(61) and inputting the third yield into a well testing model, simulating the well opening production of the gas well in the fourth preset time period by using the well testing model according to the third yield, and outputting the simulated bottom hole flowing pressure of the gas well in the fourth preset time period.

It should be noted that the fourth preset time period may be preset, and in order to make the simulated bottom hole flow pressure output by the well testing model after the well opening production of the simulated gas well at the third production rate more accurate, the fourth preset time period may be set to be longer, for example, the fourth preset time period may be 2 days, 3 days, and the like.

(62) And determining a target coordinate point according to the third yield, the simulated bottom hole flowing pressure output by the well testing model and the stratum static pressure included in the reservoir parameters.

Specifically, the third yield may be used as an abscissa of the target coordinate point, the third yield is divided by a square of a formation static pressure included in the reservoir parameters minus a square of a simulated bottom hole flowing pressure output by the well testing model, and an ordinate of the target coordinate is obtained.

(63) And determining a curve which passes through the target coordinate point and has the slope of the turbulence coefficient as a second curve.

The second curve is a curve parallel to the first curve, and the second curve has an intercept on the horizontal axis.

(64) And determining the intercept of the second curve on the horizontal axis as the laminar flow coefficient in the binomial capacity equation.

It should be noted that when the binomial capacity equation is

When it is, theThe equation can be changed into

Q is to be_gAs the abscissa, the axis of the coordinate,

as an ordinate, a straight line having an intercept a on the horizontal axis can be obtained, and since a is expressed as a laminar flow coefficient, the intercept of the second curve on the horizontal axis can be determined as the laminar flow coefficient in the binomial capacity equation.

(7) And determining the second unobstructed flow of the gas well through a binomial productivity equation according to the turbulence coefficient, the laminar flow coefficient and the formation static pressure included in the reservoir parameters.

It should be noted that when the binomial capacity equation is

When B is expressed as a turbulence coefficient, A is expressed as a laminar coefficient, P_RRepresenting the static pressure of the formation, P_wfExpressed as the bottom hole flow pressure, in this case, let P_wf＝101.325×10^-3MPa, i.e. the bottom hole flow pressure is equal to the atmospheric pressure, q is obtained_gI.e., the second unobstructed flow rate of the gas well, i.e., the maximum theoretical production that can be achieved by the gas well.

It is worth mentioning that the well testing method for the gas well provided by the embodiment of the invention takes the data during the oil testing period as the basis for predicting the yield range of the gas well, tests the gas well according to the yield range of the gas well, and finally determines the second unobstructed flow rate which can be used for evaluating the yield of the gas well.

For ease of understanding, the above-described step 2056 is described below with reference to fig. 3. Referring to fig. 3, the step 2056 may specifically include the following steps 301 to 317.

Step 301: n yields are selected from the range of gas well yields as n second yields.

Step 302: and taking the ith second yield of the n second yields as a target yield.

Step 303: and performing ith well opening production on the gas well within a third preset time length by using the target yield, and determining the instantaneous bottom hole flow pressure from the ith-1 well opening production to the ith well opening production as a first bottom hole flow pressure corresponding to the ith-1 second yield when i is not 1.

Step 304: and when the ith well opening production is completed, judging whether i is equal to n.

If not, let i be i +1, return to step 302.

If so, steps 305-317 are performed.

Step 305: and determining the instant bottom hole flow pressure when the ith well opening production is finished as the first bottom hole flow pressure corresponding to the ith second production.

Step 306: and determining the ith second yield in the n second yields as the abscissa of the coordinate point corresponding to the ith second yield.

Step 307: and subtracting the square of the first bottom hole flowing pressure corresponding to the ith second yield from the square of the static pressure of the stratum included in the reservoir parameters, and dividing the square of the first bottom hole flowing pressure corresponding to the ith second yield by the ith second yield to obtain the ordinate of the coordinate point corresponding to the ith second yield.

Step 308: and performing curve fitting on the n coordinate points which are in one-to-one correspondence with the n second yields to obtain a first curve.

Step 309: the slope of the first curve is determined as the turbulence factor in the binomial energy production equation.

Step 310: the minimum yield and the maximum yield of the n second yields are obtained.

Step 311: the yield range with the minimum value as the minimum yield and the maximum value as the maximum yield is determined as the target yield range.

Step 312: one yield is selected from the target yield range as a third yield.

Step 313: and inputting the third yield into a well testing model, simulating the well opening production of the gas well in the fourth preset time period by using the well testing model according to the third yield, and outputting the simulated bottom hole flowing pressure of the gas well in the fourth preset time period.

Step 314: and determining a target coordinate point according to the third yield, the simulated bottom hole flowing pressure output by the well testing model and the stratum static pressure included in the reservoir parameters.

Step 315: and determining a curve which passes through the target coordinate point and has the slope of the turbulence coefficient as a second curve.

Step 316: and determining the intercept of the second curve on the horizontal axis as the laminar flow coefficient in the binomial capacity equation.

Step 317: and determining the second unobstructed flow of the gas well through a binomial productivity equation according to the turbulence coefficient, the laminar flow coefficient and the formation static pressure included in the reservoir parameters.

Fig. 4 is a well testing device for a gas well according to an embodiment of the present invention, and referring to fig. 4, the device includes: an acquisition module 401, a first determination module 402, a second determination module 403, a third determination module 404 and a well testing module 405;

the acquiring module 401 is used for acquiring the oil testing yield and the wellhead oil pressure of the gas well in the well opening process of oil testing, and acquiring the wellhead oil pressure of the gas well in the well closing process of oil testing;

the first determination module 402 is used for determining the bottom hole flowing pressure of the gas well according to the wellhead oil pressure of the gas well in the well opening process of oil testing;

a second determining module 403, configured to determine a formation static pressure of the gas well according to a wellhead oil pressure of the gas well in a well shut-in process of oil testing;

a third determining module 404, configured to determine a yield range of the gas well according to the oil testing yield of the gas well in the oil testing well opening process, the bottom hole flowing pressure of the gas well, and the formation static pressure;

and the well testing module 405 is used for testing the gas well according to the production range of the gas well.

Optionally, the first determining module 402 includes:

the first acquisition unit is used for acquiring the distance between a wellhead of a gas well and a gas layer where the gas well is located;

Optionally, the second determining module 403 includes:

the second acquisition unit is used for acquiring the distance between the wellhead of the gas well and the gas layer where the gas well is located;

Optionally, the third determining module 404 includes:

the first determination unit is used for determining a first unobstructed flow of the gas well according to the oil testing yield of the gas well in the well opening process of oil testing, the bottom hole flowing pressure of the gas well and the formation static pressure;

the fourth calculation unit is used for multiplying the first choked flow quantity of the gas well by the first proportion to obtain a first numerical value; multiplying the first choked flow quantity of the gas well by a second proportion to obtain a second numerical value, wherein the second proportion is larger than the first proportion;

Optionally, the well testing module 405 comprises:

a selection unit for selecting one production from a production range of a gas well as a first production;

the first recording unit is used for carrying out open-hole production on the gas well within a first preset time length in a first yield, and recording the bottom hole flowing pressure of the gas well within the first preset time length in the open-hole production process;

the second recording unit is used for closing the gas well within a second preset time length and recording the bottom hole flowing pressure of the gas well within the second preset time length in the well closing process;

the third acquisition unit is used for acquiring logging data of a gas well;

and the third determining unit is used for determining the second unobstructed flow of the gas well according to the yield range, the well testing model and the reservoir parameters of the gas well.

Optionally, the third determining unit includes:

the first selection subunit is used for selecting n yields from the yield range of the gas well as n second yields, wherein n is an integer greater than or equal to 2;

the first determining subunit is used for determining a turbulence coefficient in the binomial productivity equation according to the n second yields and the formation static pressure included in the reservoir parameters;

an obtaining subunit configured to obtain a minimum yield and a maximum yield of the n second yields;

a second determining subunit, configured to determine a yield range with a minimum value as a minimum yield and a maximum value as a maximum yield as a target yield range;

the third determining subunit is used for determining the laminar flow coefficient in the binomial productivity equation according to the third yield, the well test model, the turbulence coefficient and the formation static pressure included in the reservoir parameters;

and the fourth determining subunit is used for determining the second unobstructed flow of the gas well through a binomial productivity equation according to the turbulence coefficient, the laminar flow coefficient and the formation static pressure included in the reservoir parameters.

Optionally, the first determining subunit is configured to:

performing curve fitting on the n coordinate points to obtain a first curve;

Optionally, the first determining subunit is configured to:

Optionally, the third determining subunit is configured to:

It should be noted that: in the well testing device for a gas well provided in the above embodiment, only the division of the above functional modules is exemplified when testing the gas well, and in practical application, the above function distribution may be completed by different functional modules according to needs, that is, the internal structure of the device is divided into different functional modules to complete all or part of the above described functions. In addition, the well testing device of the gas well provided by the embodiment and the well testing method embodiment of the gas well belong to the same concept, and the specific implementation process is detailed in the method embodiment and is not described again.

Fig. 5 is a schematic structural diagram of a well testing device for a gas well according to an embodiment of the present invention. Referring to fig. 5, the apparatus may be a terminal 500, and the terminal 500 may be: a smart phone, a tablet computer, an MP3 player (Moving picture Experts Group Audio Layer III, motion picture Experts compression standard Audio Layer 3), an MP4 player (Moving picture Experts Group Audio Layer IV, motion picture Experts compression standard Audio Layer 4), a notebook computer or a desktop computer. Terminal 500 may also be referred to by other names such as user equipment, portable terminal, laptop terminal, desktop terminal, and the like.

In general, the terminal 500 includes: a processor 501 and a memory 502.

The processor 501 may include one or more processing cores, such as a 4-core processor, an 8-core processor, and so on. The processor 501 may be implemented in at least one hardware form of a DSP (Digital Signal Processing), an FPGA (Field-Programmable Gate Array), and a PLA (Programmable Logic Array). The processor 501 may also include a main processor and a coprocessor, where the main processor is a processor for processing data in an awake state, and is also called a Central Processing Unit (CPU); a coprocessor is a low power processor for processing data in a standby state. In some embodiments, the processor 501 may be integrated with a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content required to be displayed by the display screen. In some embodiments, processor 501 may also include an AI (Artificial Intelligence) processor for processing computational operations related to machine learning.

Memory 502 may include one or more computer-readable storage media, which may be non-transitory. Memory 502 may also include high speed random access memory as well as non-volatile memory, such as one or more magnetic disk storage devices, flash memory storage devices. In some embodiments, a non-transitory computer readable storage medium in the memory 502 is used to store at least one instruction for execution by the processor 501 to implement a method of testing a gas well as provided by method embodiments herein.

In some embodiments, the terminal 500 may further optionally include: a peripheral interface 503 and at least one peripheral. The processor 501, memory 502 and peripheral interface 503 may be connected by a bus or signal lines. Each peripheral may be connected to the peripheral interface 503 by a bus, signal line, or circuit board. Specifically, the peripheral device includes: at least one of radio frequency circuitry 504, touch screen display 505, camera 506, audio circuitry 507, positioning components 508, and power supply 509.

The peripheral interface 503 may be used to connect at least one peripheral related to I/O (Input/Output) to the processor 501 and the memory 502. In some embodiments, the processor 501, memory 502, and peripheral interface 503 are integrated on the same chip or circuit board; in some other embodiments, any one or both of the processor 501, the memory 502, and the peripheral interface 503 may be implemented on separate chips or circuit boards, which are not limited in this application.

The Radio Frequency circuit 504 is used for receiving and transmitting RF (Radio Frequency) signals, also called electromagnetic signals. The radio frequency circuitry 504 communicates with communication networks and other communication devices via electromagnetic signals. The rf circuit 504 converts an electrical signal into an electromagnetic signal to transmit, or converts a received electromagnetic signal into an electrical signal. Optionally, the radio frequency circuit 504 includes: an antenna system, an RF transceiver, one or more amplifiers, a tuner, an oscillator, a digital signal processor, a codec chipset, a subscriber identity module card, etc. The radio frequency circuitry 504 may communicate with other terminals via at least one wireless communication protocol. The wireless communication protocols include, but are not limited to: metropolitan area networks, various generation mobile communication networks (2G, 3G, 4G, and 5G), Wireless local area networks, and/or WiFi (Wireless Fidelity) networks. In some embodiments, the rf circuit 504 may further include NFC (Near Field Communication) related circuits, which are not limited in this application.

The display screen 505 is used to display a UI (User Interface). The UI may include graphics, text, icons, video, and any combination thereof. When the display screen 505 is a touch display screen, the display screen 505 also has the ability to capture touch signals on or over the surface of the display screen 505. The touch signal may be input to the processor 501 as a control signal for processing. At this point, the display screen 505 may also be used to provide virtual buttons and/or a virtual keyboard, also referred to as soft buttons and/or a soft keyboard. In some embodiments, the display screen 505 may be one, disposed on the front panel of the terminal 500; in other embodiments, the display screens 505 may be at least two, respectively disposed on different surfaces of the terminal 500 or in a folded design; in still other embodiments, the display 505 may be a flexible display disposed on a curved surface or on a folded surface of the terminal 500. Even more, the display screen 505 can be arranged in a non-rectangular irregular figure, i.e. a shaped screen. The Display screen 505 may be made of LCD (Liquid Crystal Display), OLED (Organic Light-Emitting Diode), and other materials.

The camera assembly 506 is used to capture images or video. Optionally, camera assembly 506 includes a front camera and a rear camera. Generally, a front camera is disposed at a front panel of the terminal, and a rear camera is disposed at a rear surface of the terminal. In some embodiments, the number of the rear cameras is at least two, and each rear camera is any one of a main camera, a depth-of-field camera, a wide-angle camera and a telephoto camera, so that the main camera and the depth-of-field camera are fused to realize a background blurring function, and the main camera and the wide-angle camera are fused to realize panoramic shooting and VR (Virtual Reality) shooting functions or other fusion shooting functions. In some embodiments, camera assembly 506 may also include a flash. The flash lamp can be a monochrome temperature flash lamp or a bicolor temperature flash lamp. The double-color-temperature flash lamp is a combination of a warm-light flash lamp and a cold-light flash lamp, and can be used for light compensation at different color temperatures.

Audio circuitry 507 may include a microphone and a speaker. The microphone is used for collecting sound waves of a user and the environment, converting the sound waves into electric signals, and inputting the electric signals to the processor 501 for processing, or inputting the electric signals to the radio frequency circuit 504 to realize voice communication. For the purpose of stereo sound collection or noise reduction, a plurality of microphones may be provided at different portions of the terminal 500. The microphone may also be an array microphone or an omni-directional pick-up microphone. The speaker is used to convert electrical signals from the processor 501 or the radio frequency circuit 504 into sound waves. The loudspeaker can be a traditional film loudspeaker or a piezoelectric ceramic loudspeaker. When the speaker is a piezoelectric ceramic speaker, the speaker can be used for purposes such as converting an electric signal into a sound wave audible to a human being, or converting an electric signal into a sound wave inaudible to a human being to measure a distance. In some embodiments, audio circuitry 507 may also include a headphone jack.

The positioning component 508 is used to locate the current geographic position of the terminal 500 for navigation or LBS (location based Service). The positioning component 508 may be a positioning component based on the GPS (global positioning System) in the united states, the beidou System in china, the graves System in russia, or the galileo System in the european union.

Power supply 509 is used to power the various components in terminal 500. The power source 509 may be alternating current, direct current, disposable or rechargeable. When power supply 509 includes a rechargeable battery, the rechargeable battery may support wired or wireless charging. The rechargeable battery may also be used to support fast charge technology.

In some embodiments, terminal 500 also includes one or more sensors 510. The one or more sensors 510 include, but are not limited to: acceleration sensor 511, gyro sensor 512, pressure sensor 513, fingerprint sensor 514, optical sensor 515, and proximity sensor 516.

The acceleration sensor 511 may detect the magnitude of acceleration on three coordinate axes of the coordinate system established with the terminal 500. For example, the acceleration sensor 511 may be used to detect components of the gravitational acceleration in three coordinate axes. The processor 501 may control the touch screen 505 to display the user interface in a landscape view or a portrait view according to the gravitational acceleration signal collected by the acceleration sensor 511. The acceleration sensor 511 may also be used for acquisition of motion data of a game or a user.

The gyro sensor 512 may detect a body direction and a rotation angle of the terminal 500, and the gyro sensor 512 may cooperate with the acceleration sensor 511 to acquire a 3D motion of the user on the terminal 500. The processor 501 may implement the following functions according to the data collected by the gyro sensor 512: motion sensing (such as changing the UI according to a user's tilting operation), image stabilization at the time of photographing, game control, and inertial navigation.

The pressure sensor 513 may be disposed on a side bezel of the terminal 500 and/or an underlying layer of the touch display screen 505. When the pressure sensor 513 is disposed on the side frame of the terminal 500, a user's holding signal of the terminal 500 may be detected, and the processor 501 performs left-right hand recognition or shortcut operation according to the holding signal collected by the pressure sensor 513. When the pressure sensor 513 is disposed at the lower layer of the touch display screen 505, the processor 501 controls the operability control on the UI interface according to the pressure operation of the user on the touch display screen 505. The operability control comprises at least one of a button control, a scroll bar control, an icon control and a menu control.

The fingerprint sensor 514 is used for collecting a fingerprint of the user, and the processor 501 identifies the identity of the user according to the fingerprint collected by the fingerprint sensor 514, or the fingerprint sensor 514 identifies the identity of the user according to the collected fingerprint. Upon recognizing that the user's identity is a trusted identity, the processor 501 authorizes the user to perform relevant sensitive operations including unlocking the screen, viewing encrypted information, downloading software, paying, and changing settings, etc. The fingerprint sensor 514 may be disposed on the front, back, or side of the terminal 500. When a physical button or a vendor Logo is provided on the terminal 500, the fingerprint sensor 514 may be integrated with the physical button or the vendor Logo.

The optical sensor 515 is used to collect the ambient light intensity. In one embodiment, the processor 501 may control the display brightness of the touch display screen 505 based on the ambient light intensity collected by the optical sensor 515. Specifically, when the ambient light intensity is high, the display brightness of the touch display screen 505 is increased; when the ambient light intensity is low, the display brightness of the touch display screen 505 is turned down. In another embodiment, processor 501 may also dynamically adjust the shooting parameters of camera head assembly 506 based on the ambient light intensity collected by optical sensor 515.

The proximity sensor 516, also referred to as a distance sensor, is generally disposed on a front panel of the terminal 500. The proximity sensor 516 is used to collect the distance between the user and the front surface of the terminal 500. In one embodiment, when the proximity sensor 516 detects that the distance between the user and the front surface of the terminal 500 gradually decreases, the processor 501 controls the touch display screen 505 to switch from the bright screen state to the dark screen state; when the proximity sensor 516 detects that the distance between the user and the front surface of the terminal 500 becomes gradually larger, the processor 501 controls the touch display screen 505 to switch from the screen-rest state to the screen-on state.

Those skilled in the art will appreciate that the configuration shown in fig. 5 is not intended to be limiting of terminal 500 and may include more or fewer components than those shown, or some components may be combined, or a different arrangement of components may be used.

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 above-mentioned storage medium may be a read-only memory, a magnetic disk or an optical disk, etc.

The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, and any modifications, equivalents, improvements and the like that fall within the spirit and principle of the present invention are intended to be included therein.

Claims

1. A method of testing a gas well, the method comprising:

and testing the gas well according to the yield range of the gas well.

2. The method of claim 1, wherein determining the bottom hole flow pressure of the gas well based on the wellhead oil pressure of the gas well during the well opening of the test oil comprises:

3. The method of claim 1, wherein determining the static formation pressure of the gas well based on the wellhead oil pressure of the gas well during shut-in of the test oil comprises:

4. The method of claim 1, wherein determining the production range of the gas well based on the production test of the gas well during the well opening of the test, the bottom hole flow pressure of the gas well, and the static formation pressure comprises:

5. The method of any one of claims 1-4, wherein the testing the gas well for a range of production from the gas well comprises:

acquiring logging data of the gas well;

6. The method of claim 5, wherein determining a second unobstructed flow rate for the gas well based on the production spread of the gas well, the well test model, and the reservoir parameters comprises:

acquiring a minimum yield and a maximum yield of the n second yields;

selecting one yield from the target yield range as a third yield;

7. The method of claim 6, wherein determining the turbulence factor in the binomial productivity equation based on the n second productions and the static formation pressures included in the reservoir parameters comprises:

performing curve fitting on the n coordinate points to obtain a first curve;

8. The method of claim 7, wherein determining n coordinate points in one-to-one correspondence with the n second productions based on the n second productions, the first bottom hole flow pressure corresponding to each of the n second productions, and the static formation pressure included in the reservoir parameters comprises:

9. The method of any of claims 6-8, wherein determining the laminar flow coefficients in the binomial productivity equation based on the third production, the well test model, the turbulence coefficients, and a static formation pressure included in the reservoir parameters comprises:

10. A well testing device for a gas well, the device comprising:

11. The apparatus of claim 10, wherein the first determining module comprises:

12. The apparatus of claim 10, wherein the second determining module comprises:

13. The apparatus of claim 10, wherein the third determining module comprises:

14. The apparatus of any of claims 10-13, wherein the well testing module comprises:

the third acquisition unit is used for acquiring logging data of the gas well;

15. The apparatus of claim 14, wherein the third determining unit comprises:

16. The apparatus of claim 15, wherein the first determining subunit is to:

performing curve fitting on the n coordinate points to obtain a first curve;

17. The apparatus of claim 16, wherein the first determining subunit is to:

18. The apparatus of any of claims 15-17, wherein the third determining subunit is to:

19. A computer-readable storage medium having instructions stored thereon, wherein the instructions, when executed by a processor, implement the steps of any of the methods of claims 1-9.